Flood Control Method in Fields with Hard-To-Recover Reserves

2021 ◽  
Author(s):  
Alexander Viktorovich Syundyukov ◽  
Galiaskar Ismagilovich Khabibullin ◽  
Alexander Stanislavovich Trofimchuk ◽  
Denis Radikovich Shaikhatdarov ◽  
Damir Kambirovich Sagitov
Keyword(s):  
Flood Control ◽  
Control Method ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Hole Pressure ◽  
Oil Displacement ◽  
Maintenance System ◽  
Bottom Hole Pressure ◽  
Bottom Hole ◽  
Half Length

Abstract This paper presents a method for predicting the development of Auto-HF (crack) in injection wells of the reservoir pressure maintenance system during the development of low-permeable reservoirs, in order to ensure the optimal front of oil displacement by water by regulating the bottom-hole pressure of injection wells based on the derived dependence of the half-length of the Auto-HF (crack).

scholarly journals New Method for Calculating Bottom Hole Pressure of Horizontal Well in Fracture-cavity Reservoir Based on Point Source Function

2021 ◽  
Author(s):  
Hailong Liu
Keyword(s):  
Point Source ◽  
Carbonate Rock ◽  
Horizontal Well ◽  
Source Function ◽  
Stress Sensitivity ◽  
Pressure Derivative ◽  
Hole Pressure ◽  
Bottom Hole Pressure ◽  
Bottom Hole ◽  
Half Length

Abstract Accurate determination of unsteady bottom hole pressure helps to monitor and predict well production in real-time. On the premise of fully considering the seepage characteristics of carbonate rock, a new source function suitable for the seepage of carbonate rock is established. It enlarges the application scope of source function theory and lays a theoretical foundation for solving the seepage problem of carbonate rock. This paper presents the process of solving bottom hole pressure step by step. Step 1: Based on the triple media model, the Pedrosa permeability calculation formula is applied to establish the seepage model of the triple media reservoir considering the formation stress sensitivity. Step 2: By perturbation transform and Laplace transform, the point source function considering stress sensitivity in carbonate reservoir is obtained in Laplace space. The point source function in the infinite plate reservoir is obtained by the principle of mirror image and superposition. Step 3: The method of solving the horizontal well pressure under the constant pressure boundary is established. Through literature comparison and numerical simulation, the rationality of the proposed method is verified. Simultaneously, the sensitivity analysis of pressure and pressure derivative is carried out, and the influences of fracture number, fracture angle, fracture half-length, skin factor, horizontal well segment length, and horizontal well segment spacing on pressure and pressure derivative are analyzed in detail. Considering fracture orientation and stress sensitivity, we divide the triple media fracture-vuggy reservoir fluid flow into five stages. The number of fractures and fracture direction mainly affect stage C. In contrast, the length of horizontal subsection and skin factor mainly affect stage B. Stage D is more obvious when the fracture half-length and the horizontal sublevel interval of the horizontal well are small.

scholarly journals Production behavior evaluation on multilayer commingled stress-sensitive carbonate gas reservoir

2020 ◽  
pp. 014459872096415
Author(s):  
Jianlin Guo ◽  
Fankun Meng ◽  
Ailin Jia ◽  
Shuo Dong ◽  
Haijun Yan ◽  
...  
Keyword(s):  
Early Stage ◽  
Sedimentary Environment ◽  
Production Performance ◽  
Total Production ◽  
Inversion Algorithm ◽  
Gas Reservoir ◽  
Hole Pressure ◽  
Bottom Hole Pressure ◽  
Bottom Hole ◽  
Production Behavior

Influenced by the complex sedimentary environment, a well always penetrates multiple layers with different properties, which leads to the difficulty of analyzing the production behavior for each layer. Therefore, in this paper, a semi-analytical model to evaluate the production performance of each layer in a stress-sensitive multilayer carbonated gas reservoir is proposed. The flow of fluids in layers composed of matrix, fractures, and vugs can be described by triple-porosity/single permeability model, and the other layers could be characterized by single porosity media. The stress-sensitive exponents for different layers are determined by laboratory experiments and curve fitting, which are considered in pseudo-pressure and pseudo-time factor. Laplace transformation, Duhamel convolution, Stehfest inversion algorithm are used to solve the proposed model. Through the comparison with the classical solution, and the matching with real bottom-hole pressure data, the accuracy of the presented model is verified. A synthetic case which has two layers, where the first one is tight and the second one is full of fractures and vugs, is utilized to study the effects of stress-sensitive exponents, skin factors, formation radius and permeability for these two layers on production performance. The results demonstrate that the initial well production is mainly derived from high permeable layer, which causes that with the rise of formation permeability and radius, and the decrease of stress-sensitive exponents and skin factors, in the early stage, the bottom-hole pressure and the second layer production rate will increase. While the first layer contributes a lot to the total production in the later period, the well bottom-hole pressure is more influenced by the variation of formation and well condition parameters at the later stage. Compared with the second layer, the scales of formation permeability and skin factor for first layer have significant impacts on production behaviors.

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