Pressure-Transient Analysis for Cold-Water Injection into a Reservoir Coupled with Wellbore-Transient-Temperature Effects

2020 ◽  
Author(s):  
Daniel O'Reilly ◽  
Manouchehr Haghighi ◽  
Matthew Flett ◽  
Mohammad Sayyafzadeh
Keyword(s):  
Temperature Effects ◽  
Transient Analysis ◽  
Cold Water ◽  
Water Injection ◽  
Transient Temperature ◽  
Pressure Transient Analysis ◽  
Pressure Transient

scholarly journals Fractured water injection wells: Pressure transient analysis

2014 ◽  
Vol 51 (11-12) ◽  
pp. 2116-2122 ◽  
Author(s):  
V.V. Shelukhin ◽  
V.A. Baikov ◽  
S.V. Golovin ◽  
A.Y. Davletbaev ◽  
V.N. Starovoitov
Keyword(s):  
Transient Analysis ◽  
Water Injection ◽  
Injection Wells ◽  
Pressure Transient Analysis ◽  
Pressure Transient

scholarly journals A Two-Phase Flow Model for Pressure Transient Analysis of Water Injection Well considering Water Imbibition in Natural Fractured Reservoirs

2018 ◽  
Vol 2018 ◽  
pp. 1-12
Author(s):  
Mengmeng Li ◽  
Qi Li ◽  
Gang Bi ◽  
Jiaen Lin
Keyword(s):  
Transient Analysis ◽  
Two Phase Flow ◽  
Fractured Reservoirs ◽  
Water Injection ◽  
Injection Well ◽  
Phase Flow ◽  
Two Phase ◽  
Pressure Transient Analysis ◽  
Pressure Transient ◽  
Water Imbibition

The pressure injection falloff test for water injection well has the advantages of briefness and convenience, with no effect on the oil production. It has been widely used in the oil field. Tremendous attention has been focused on oil-water two-phase flow model based on the Perrine-Martin theory. However, the saturation gradient is not considered in the Perrine-Martin method, which may result in errors in computation. Moreover, water imbibition is important for water flooding in natural fractured reservoirs, while the pressure transient analysis model has rarely considered water imbibition. In this paper, we proposed a semianalytical oil-water two-phase flow imbibition model for pressure transient analysis of a water injection well in natural fractured reservoirs. The parameters in this model, including total compressibility coefficient, interporosity flow coefficient, and total mobility, change with water saturation. The model was solved by Laplace transform finite-difference (LTFD) method coupled with the quasi-stationary method. Based on the solution, the model was verified by the analytical method and a field water injection test. The features of typical curves and the influences of the parameters on the typical curves were analyzed. Results show that the shape of pressure curves for single phase flow resembles two-phase flow, but the position of the two-phase flow curves is on the upper right of the single phase flow curves. The skin factor and wellbore storage coefficient mainly influence the peak value of the pressure derivatives and the straight line of the early period. The shape factor has a major effect on the position of the “dip” of pressure derivatives. The imbibition rate coefficient mainly influences the whole system radial flow period of the curves. This work provides valuable information in the design and evaluation of stimulation treatments in natural fractured reservoirs.

Pressure Transient Analysis for a Unique Shale Gas Condensate Well, Actual Field Case

2017 ◽  
Author(s):  
M. Ibrahim ◽  
C. Pieprzica ◽  
E. Vosburgh ◽  
A. Dabral ◽  
O. Olayinka ◽  
...  
Keyword(s):  
Shale Gas ◽  
Transient Analysis ◽  
Gas Condensate ◽  
Pressure Transient Analysis ◽  
Pressure Transient ◽  
Field Case ◽  
Actual Field
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