Pressure Analysis of an Unstimulated Horizontal Well With Type Curves

1991 ◽  
Vol 43 (08) ◽  
pp. 988-993 ◽  
Author(s):  
J.R. Duda ◽  
S.P. Salamy ◽  
Khashayar Aminian ◽  
Samuel Ameri
Keyword(s):  
Horizontal Well ◽  
Type Curves ◽  
Pressure Analysis

Pressure Transient Behavior for Alternating Polymer Flooding in a Three-zone Composite Reservoir

2017 ◽  
Vol 25 (1) ◽  
pp. 1-10 ◽  
Author(s):  
Changyu Zhu ◽  
Shiqing Cheng ◽  
Youwei He ◽  
Engao Tang ◽  
Xiaodong Kang ◽  
...  
Keyword(s):  
History Matching ◽  
Petroleum Industry ◽  
Composite Model ◽  
Polymer Flooding ◽  
Analysis Model ◽  
High Concentration ◽  
Pressure Derivative ◽  
Type Curves ◽  
Formation Evaluation ◽  
Pressure Analysis

Alternating polymer flooding has achieved great attractions recently in oil industry, however, the research of pressure analysis in alternating polymer flooding reservoir is rare. This work presents a numerical pressure analysis method of three-zone composite model for formation evaluation. A new numerical pressure analysis model (three-zone composite model) is established by considering diffusion, convection, shear, and inaccessible pore volume, which is based on the rheology experiments. Based on this model, the type curves are then developed and sensitivity analysis is further conducted. The type curves have seven regimes in three-zone composite model. The characteristic is the obvious upturn of pressure derivative curve in transient regime between low concentration and high concentration polymer solution. Formation parameters can be interpreted by history matching and formation evaluation can be conducted based on this model. As an important part of formation evaluation, formation damage as a result of adsorption of polymers in porous media is evaluated by comparing the interpreted permeability with the original value before polymer flooding. The field test data proves that this proposed method can accurately evaluate reservoir characteristics in alternating polymer flooding reservoirs, which emphasizes the potential application of this method in petroleum industry.

The Foundation and Application of Horizontal Well Deliverability Type Curves

2011 ◽  
Author(s):  
Rong Wang ◽  
Yonggang Duan ◽  
Quantang Fang ◽  
Cao Tingkuan ◽  
Mingqiang Wei
Keyword(s):  
Horizontal Well ◽  
Type Curves

Transient pressure analysis of horizontal well in low permeability oil reservoir

2015 ◽  
Vol 10 (1) ◽  
pp. 23
Author(s):  
Yu Long Zhao ◽  
Lie Hui Zhang ◽  
Jin Zhou Zhao ◽  
Shu Yong Hu ◽  
Bo Ning Zhang
Keyword(s):  
Horizontal Well ◽  
Low Permeability ◽  
Oil Reservoir ◽  
Transient Pressure ◽  
Transient Pressure Analysis ◽  
Pressure Analysis

A Semianalytical Model for Horizontal-Well Productivity With Pressure Drop Along the Wellbore

SPE Journal ◽  
2018 ◽  
Vol 23 (05) ◽  
pp. 1603-1614 ◽  
Author(s):  
Wanjing Luo ◽  
Changfu Tang ◽  
Yin Feng
Keyword(s):  
Reynolds Number ◽  
Fluid Flow ◽  
Pressure Drop ◽  
Horizontal Well ◽  
Horizontal Wells ◽  
Productivity Index ◽  
Type Curves ◽  
Penetration Ratio ◽  
New Type ◽  
The One

Summary This study aims to develop a semianalytical model to calculate the productivity index (PI) of a horizontal well with pressure drop along the wellbore. It has been indicated that by introducing novel definitions of horizontal-well permeability and conductivity, the equation of fluid flow along a horizontal well with pressure drop has the same form as the one for fluid flow in a varying-conductivity fracture. Thus, the varying-conductivity-fracture model and PI model can be used to obtain the PI of a horizontal well. Results indicate that the PI of a horizontal well depends on the interaction between horizontal-well conductivity, penetration ratio, and Reynolds number. New type curves of the penetration ratios with various combinations of parameters have been presented. A complete-penetration zone and a partial-penetration zone can be identified on the type curves. Based on the type curves, two examples have also been presented to illustrate the advantages of this work in optimizing parameters of horizontal wells.

Transient pressure analysis of a horizontal well with multiple, arbitrarily shaped horizontal fractures

2019 ◽  
Vol 180 ◽  
pp. 631-642 ◽  
Author(s):  
Hongyang Chu ◽  
Xinwei Liao ◽  
Zhiming Chen ◽  
Xiaoliang Zhao ◽  
Wenyuan Liu ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Transient Pressure ◽  
Transient Pressure Analysis ◽  
Pressure Analysis

Horizontal Well Pressure Analysis

1989 ◽  
Vol 4 (04) ◽  
pp. 567-575 ◽  
Author(s):  
E. Ozkan ◽  
R. Raghavan ◽  
S.D. Joshi
Keyword(s):  
Horizontal Well ◽  
Pressure Analysis

Optimizing the Number of Fractures in a Horizontal Well

SPE Journal ◽  
2019 ◽  
Vol 24 (03) ◽  
pp. 1364-1377 ◽  
Author(s):  
Vyacheslav Guk ◽  
Mikhail Tuzovskiy ◽  
Don Wolcott ◽  
Joe Mach
Keyword(s):  
Horizontal Well ◽  
Horizontal Wells ◽  
Optimal Number ◽  
Hydraulic Fractures ◽  
Single Fracture ◽  
Multiple Fracture ◽  
Multiple Fractures ◽  
Type Curves ◽  
Fracture Width ◽  
Technical Potential

Summary Horizontal wells with multiple hydraulic fractures have become a standard completion for the development of tight oil and gas reservoirs. Successful optimization of multiple-fracture design on horizontal wells began empirically in the Barnett Shale in the late 1990s (Steward 2013; Gertner 2013). More recently, research has focused on further improving fracturing performance by developing a model-derived optimum. Some researchers have focused on an economic optimum on the basis of multiple runs of an analytical or numerical model (Zhang et al. 2012; Saputelli et al. 2014). With such an approach, a new set of model runs is necessary to optimize the design each time the input parameters change significantly. Running multiple simulations for every optimization case might not always be practical. An alternative approach is to develop well-performance curves with dimensionless variables on the basis of the performance model. Such an approach was the basis for unified fracture design (UFD) for a single fracture in a vertical well (Economides et al. 2002). However, a similar systemized method to calculate the optimum for a horizontal well with multiple hydraulic fractures was missing. The objective of this study was to develop a rigorous and unified dimensionless optimization technique with type curves for the case of multiple transverse fractures in a horizontal well—an extension of UFD. The mathematical problem was solved in dimensionless variables. Multiple fractures include the proppant number (NP), penetration ratio (Ix), dimensionless conductivity (CfD), and aspect ratio (yeD) for each fracture, which is inversely proportional to the number of fractures. The direct boundary element (DBE) method was used to generate the dimensionless productivity index (JD) for a given range of these parameters (28,000 runs) for the pseudosteady-state case. Finally, total well JD was plotted as a function of the number of fractures for various NP. The effect of minimum fracture width was studied, and the optimization curves were adjusted for three cases of minimum fracture width. The provided dimensionless type curves can be used to identify the optimized number of fractures and their geometry for a given set of parameters, without running a more complicated numerical model multiple times. First, the proppant mass (and hence, NP) used for the fracture design can be selected on the basis of economic or other considerations. For this purpose, a relationship between total JD and NP, which accounts for the minimum fracture width requirement, was provided. Then, the optimal number of fractures can be calculated for a given NP using the generated type curves with minimum width constraints. The following observations were made during the study on the basis of the performed runs: For a given volume or proppant, NP, total JD for multiple fractures increases to an asymptote as the number of fractures increases. This asymptote represents a technical potential for multiple fractures and for high proppant numbers (NP≥100), with a technical potential of 3πNP. Below this asymptote, the more fractures that are created for a fixed NP, the larger the JD. In practice, minimum fracture width constrains the fracture geometry, and therefore maximum JD. For the case when 20/40 sand is used for multiple hydraulic fracturing of a 0.01-md formation with square total area, the optimal number of factures is approximately NP25. Application of horizontal drilling technology with multiple fractures assumes the availability of high proppant numbers. It was shown mathematically that the alternative low proppant numbers (NP≤20 for the previous case) are impractical for multiple fractures, because total JD cannot be significantly higher than JD for an optimized single fracture in the same area. This means that low formation permeability and/or high proppant volumes are needed for multiple fracture treatments.

Performance Evaluation of a Horizontal Well With Multiple Fractures by Use of a Slab-Source Function

SPE Journal ◽  
2015 ◽  
Vol 20 (03) ◽  
pp. 652-662 ◽  
Author(s):  
Daoyong Yang ◽  
Feng Zhang ◽  
John A. Styles ◽  
Junmin Gao
Keyword(s):  
Horizontal Well ◽  
Source Function ◽  
Early Stage ◽  
Pressure Response ◽  
Multiple Fractures ◽  
Fracture Conductivity ◽  
Linear Flow ◽  
Type Curves ◽  
Semianalytical Method ◽  
Reservoir Simulator

Summary A novel slab-source function was formulated and successfully applied to accurately evaluate performance of a horizontal well with multiple fractures in a tight formation. More specifically, such a slab-source function in the Laplace domain has assigned a geometrical dimension to the source, whereas pressure response of a rectangular reservoir with closed outer boundaries can be determined. A semianalytical method is then applied to solve the newly formulated mathematical model by discretizing the fracture into small segments, each of which is treated as a slab source, assuming that there exists unsteady flow between the adjacent segments. The newly developed function was validated with numerical solution obtained from a reservoir simulator and then its application was extended to a field case. The pressure response together with its corresponding derivative type curves was reproduced to examine effects of number of stages, fracture conductivity, and fracture dimension under various penetration conditions. The fracture conductivity is found to mainly influence early-stage bilinear-/linear-flow regime, whereas a smaller conductivity will force more fluid to enter the toe of the fracture than its heel. The penetrating ratio will impose a significant impact on the pressure response at the early stage, forcing the bilinear/linear flow to become radial flow.

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