MPE Mathematical Problems in Engineering 1563-5147 1024-123X Hindawi Publishing Corporation 10.1155/2015/726910 726910 Research Article An Analytical Solution of Partially Penetrating Hydraulic Fractures in a Box-Shaped Reservoir Zhang He 1, 2 Wang Xiaodong 1, 2 Wang Lei 1, 2 Li Shaofan 1 School of Energy Resources China University of Geosciences Beijing 100083 China cugb.edu.cn 2 Beijing Key Laboratory of Unconventional Natural Gas Geology Evaluation and Development Engineering Beijing 100083 China 2015 2362015 2015 19 08 2014 08 12 2014 08 12 2014 2362015 2015 Copyright © 2015 He Zhang et al. This is an open access article distributed under the Creative Commons Attribution License, which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.

This paper presents a new method to give an analytical solution in Laplace domain directly that is used to describe pressure transient behavior of partially penetrating hydraulic fractures in a box-shaped reservoir with closed boundaries. The basic building block of the method is to solve diffusivity equation with the integration of Dirac function over the distance that is presented for the first time. Different from the traditional method of using the source solution and Green’s function presented by Gringarten and Ramey, this paper uses Laplace transform and Fourier transform to solve the diffusivity equation and the analytical solution obtained is accurate and simple. The effects of parameters including fracture height, fracture length, the position of the fracture, and reservoir width on the pressure and pressure derivative are fully investigated. The advantage of the analytical solution is easy to incorporate storage coefficient and skin factor. It can also reduce the amount of computation and compute efficiently and quickly.

1. Introduction

Hydraulic fracturing technology has been a common application in the oil and gas industry during the last two decades. More and more attentions were focused on the study of pressure transient behavior of hydraulically fractured wells. In most published literatures, hydraulic fractures were assumed to be fully penetrating the formation. Limited efforts have been made to investigate the effects of partially penetrating fracture height on the performance of wells. In practice, fully penetrating fractures may lead to an early or immediate water or gas breakthrough in a reservoir with bottom water or gas cap in contact, whereas partially penetrating fractures may be the only way to prevent the early breakthrough .

No matter the problem of wells with or without hydraulic fractures, most scholars considered the fully penetrating wells or fully penetrating hydraulic fractures. However the issue of partial penetration is always ignored. In the early time, some scholars presented some methods to study partially penetrating wells. Muskat, Nisle, Brons and Marting, and Papatzacos used the method of images , Streltsova-Adams  used Laplace and Hankel transformations, and Buhidma and Raghavan  used Green’s function to solve the problem to partial penetration well in a reservoir. Later Yeh and Reynolds  used a numerical simulator to present some type curves for partial penetration, multilayered reservoirs with transient crossflow. In the late time, Ozkan and Raghavan  proposed a solution for a limited-entry slanted well in an infinite reservoir with closed top and bottom boundaries using the Laplace transformation and Bui et al.  used the double-porosity formulation of Warren and Root for naturally fractured reservoir. Fuentes-Cruz and Camacho-Velazquez  obtained the pressure transient behavior for partially penetrating wells completed in naturally fractured-vuggy reservoir by combination of Laplace transformation and finite Fourier transformation.

To solve the unsteady-state flow problem of fractures in the reservoir, most solutions were presented based on the using of the source solution and Green’s function provided by Gringarten and Ramey  which can be used in combination with Newman’s product method to generate solutions for different reservoir flow problem. At first, the pressure behavior of the partially penetrating fractures was presented by Gringarten and Ramey Jr.  using Green’s function. But the physical model only considered the closed upper and lower boundaries. Raghavan et al.  presented an analytical model that researched the effect of the vertical fracture height on the pressure transient behavior of a partially penetrated uniform-flux fractured well by evaluating the uniform-flux solution at a point in the fracture which was assumed to yield the infinite-conductivity solution. This model was an extension of the case of fully penetrating vertical fracture previously found by Gringarten et al. Rodriguez et al. [14, 15] presented semianalytical solution of the pressure transient behavior in a homogeneous and isotropic reservoir with a well intersected by a partially penetrating single vertical fracture of finite or infinite conductivity. However they did not investigate the effect of vertical fracture position on the wellbore pressure.

These previous solutions were quite significant to the later analysis of the pressure behavior of the partially penetrating fractures. Valkó and Amini  presented a method of distributed volume sources (DVS) to investigate a horizontal well with multiple transverse fractures in a box-shaped reservoir. The diffusivity equation considered a source term to calculate the pressure distribution and compute the production rate from a fracture. But it was only an approximate approach. Alpheus and Tiab  presented the analysis of the solution to the effect of partial penetration of an infinite conductivity hydraulic fracture on the pressure behavior of horizontal well extending in naturally fractured reservoirs. They founded that the duration of early linear flow regime is a function of the hydraulic fractures height. Although the mathematical model was obtained in Laplace domain with elliptical flow model, the method was complex and unclear because of the model that was obtained indirectly. Al Rbeawi and Tiab [1, 2] presented an analytical model in real time domain for the pressure behavior of a horizontal well with multiple vertical and inclined partially penetrating hydraulic fractures in an infinite homogenous reservoir to explain the pressure transient tests and forecast productivity of the well by using the instantaneous source function in three principal directions. Moreover, Lin and Zhu  developed a slab source method to evaluate performance of horizontal wells with or without fractures with consideration of the three-dimensional fracture geometry. However, the solution was also derived in real time domain, making it difficult to incorporate storage coefficient and skin factor that are usually obtained from the Laplace domain solution.

This study attempts to give some new insights in understanding the partially penetrating hydraulic fractures in a box-shaped reservoir. This paper presents an analytical solution that describes pressure transient behavior of partially penetrating fractures in a box-shaped reservoir and is successfully applied to examine effects of fracture half height, fracture half length, and reservoir width on performance of a fracture in a reservoir with closed boundaries based on pressure and pressure derivative concepts. Moreover the effect of the vertical position of the fracture on the pressure and pressure derivative is fully investigated. More specifically, the diffusivity equation is presented for the first time and the analytical solution of pressure transient behavior in Laplace domain is derived by using Laplace transform and Fourier transform. Then the bottomhole pressure in the real time domain can be obtained by using the inverse Laplace algorithm as proposed by Stehfest  subsequently. The result is validated accurately by comparing with previous results in the literature. The advantages of Laplace domain solution are that it can make it easy to incorporate storage coefficient and skin factor, can reduce the amount of computation, and improve the computational efficiently because it is unnecessary to scatter time.

2. Mathematical Model

Consider a partially penetrating hydraulic fracture in a closed homogenous box-shaped reservoir as shown in Figure 1. If we assume that all fluid withdrawal will be through the fracture, the fracture is partially penetrating the formation and the fracture can be simulated as plane source .

Schematic diagram of partially penetrating fracture.

As shown in Figure 1, a partially penetrating fracture is placed in a reservoir with height ( z direction) z e , length ( x direction) x e , and width ( y direction) y e , having its dimension 2 w x in x direction and 2 w z in z direction. The formation has horizontal and vertical permeability k h and k z , respectively. The fracture is assumed to be infinitely conductive and its position is ( c x , c y , c z ). The pressure is uniform initially throughout the reservoir and equal to p i .

The analytical model for the pressure behavior of a fracture in a box-shaped reservoir can be derived based on the solution for the diffusivity equation in the porous media. The diffusivity equation that governs the flow is (1) η h 2 P x 2 + η h 2 P y 2 + η z 2 P z 2 + Q B ϕ c t H 1 × H 2 × H 3 = P t , where ϕ is porosity, c t is total compressibility, t is the time, p is reservoir pressure, and B is formation volume factor. The well produces slightly compressible fluid with constant viscosity μ at the total flow rate of Q , where (2) η h = k h ϕ μ c t η z = k z ϕ μ c t . We should notice that (3) Q B = q 2 w x 2 w z , where q is the fluid withdraw per unit fracture surface area.

Reservoir pressure is initially constant (4) p x , y , z , 0 = p i . The outer boundaries are assumed to be closed so that (5) p x x = 0 , x e = 0 p y y = 0 , y e = 0 p z z = 0 , z e = 0 , H 1 , H 2 , and H 3 can be written, respectively, as (6) H 1 = c x - w x c x + w x 1 2 w x δ x - c x d c x H 2 = δ y - c y H 3 = c z - w z c z + w z 1 2 w z δ z - c z d c z , where δ is Dirac function.

To simplify the problem we define dimensionless variables as the follows: (7) P D = 2 π k h z e p i - p Q B μ t D = k h t ϕ μ c t L 2 k h = k x k y L D = z e L k h k z x D = x L y D = y L z D = z z e x e D = x e L y e D = y e L z e D = z e z e = 1 w x D = w x L w z D = w z z e c x D = c x L c y D = c y L c z D = c z z e , where L is the reference length.

Using the dimensionless variables (1) can be written as (8) 2 P D x D 2 + 2 P D y D 2 + 2 P D L D 2 z D 2 + 2 π H 1 D × H 2 D × H 3 D = P D t D , where H 1 , H 2 , and H 3 can be written as (9) H 1 D = c x D - w x D c x D + w x D 1 2 w x D δ x D - c x D d c x D H 2 D = δ y D - c y D H 3 D = c z D - w z D c z D + w z D 1 2 w z D δ z D - c z D d c z D with (10) I.C.:    p D ( x D , y D , z D , 0 ) = 0 B.C.s:       p D x D x D = 0 , x e D = 0 p D y D y D = 0 , y e D = 0 p D z D z D = 0 , z e D = 0 .

The Laplace transform with respect to time is defined as (11) p ~ D r D , s = 0 p D r D , s e - s t D d t D . By applying Laplace transform to (8), we obtain (12) 2 p ~ D x D 2 + 2 p ~ D y D 2 + 2 p ~ D L D 2 z D 2 + 2 π H 1 D × H 2 D × H 3 D s = s p ~ D . Outer boundary conditions in Laplace space are (13) p ~ D x D x D = 0 , x e D = 0 p ~ D y D y D = 0 , y e D = 0 p ~ D z D z D = 0 , z e D = 0 .

Fourier cosine transform with respect to x D can be defined as (14) p - D u n = 0 x e D p D cos u n x D d x D . The characteristic equation is defined as (15) sin u m x e D = 0 . By solving (15), the characteristic number is obtained as follows: (16) u m = m π x e D .

Based on the concept of Fourier cosine transform, the Fourier transform of the H 1 D , H 2 D , and H 3 D function, respectively, is (17a) H - 1 D = 0 x e D c x D - w x D c x D + w x D 1 2 w x D δ x D - c x D d c x D · cos u m x D d x D = sin u m ( c x D + w x D ) - sin u m ( c x D - w x D ) 2 u m w x D (17b) H - 2 D = 0 y e D δ y D - c y D cos v n y D d y D = cos ( v n c y D ) (17c) H - 3 D = 0 z e D c z D - w z D c z D + w z D 1 2 w z D δ z D - c z D d c z D · cos w p z D d z D = sin w p c z D + w z D - sin w p c z D - w z D 2 w p w z D . The first Fourier cosine transform of (12) on the variable x D is (18) - u m 2 p ~ - D + 2 p ~ D y D 2 + 2 p ~ D L D 2 z D 2 + 2 π H - 1 D × H 2 D × H 3 D s = s p ~ - D . The second Fourier cosine transform of (18) on the variable y D is (19) - u m 2 p ~ - - D - v n 2 p ~ - - D + 2 p ~ - - D L D 2 z D 2 + 2 π H - 1 D × H - 2 D × H 3 D s = s p ~ - - D . For the third Fourier cosine transform of (19) on the variable z D , we obtain (20) - u m 2 p ~ - - - D - v n 2 p ~ - - - D - w p 2 L D 2 p ~ - - - D + 2 π H - 1 D × H - 2 D × H - 3 D s = s p ~ - - - D , where (21) u m = m π x e D v n = n π y e D w p = p π z e D . According to the following equation (22) P D x D = m = 1 cos u m x D N n P - D u m taking the first Fourier inverse transform of (20) on the variable z D , the solution can be expressed as follows: (23) s p ~ - - D = 2 π 1 z e D H - 1 D × H - 2 D × 1 ( s + u m 2 + v n 2 ) + 2 π H - 1 D × H - 2 D × 2 z e D p = 1 cos w p z D H - 3 D 1 s + u m 2 + v n 2 + w p 2 / L D 2 . The second Fourier inverse transform of (19) on the variable y D is (24) s p ~ - D = 2 π 1 y e D 1 z e D H - 1 D ( s + u m 2 ) + 2 π 2 y e D H - 1 D n = 1 1 z e D cos ( v n y D ) H - 2 D ( s + u m 2 + v n 2 ) + 2 π 1 y e D H - 1 D 2 z e D p = 1 cos ( w p z D ) H - 3 D ( s + u m 2 + w p 2 / L D 2 ) + 2 π 2 y e D 2 z e D H - 1 D × n = 1 p = 1 cos v n y D cos w p z D · H - 2 D H - 3 D s + u m 2 + v n 2 + w p 2 / L D 2 . The third Fourier inverse transform of (18) on the variable x D is (25) s p ~ D = 2 π x e D y e D z e D s + 4 π x e D y e D z e D m = 1 cos ( u m x D ) H - 1 D ( s + u m 2 ) + 4 π x e D y e D z e D n = 1 cos ( v n y D ) H - 2 D ( s + v n 2 ) + 8 π x e D y e D z e D · n = 1 m = 1 cos ( v n y D ) cos ( u m x D ) H - 1 D H - 2 D ( s + u m 2 + v n 2 ) + 4 π x e D y e D z e D p = 1 cos ( w p z D ) H - 3 D ( s + w p 2 / L D 2 ) + 8 π x e D y e D z e D · m = 1 p = 1 cos ( w p z D ) cos ( u m x D ) H - 1 D H - 3 D ( s + u m 2 + w p 2 / L D 2 ) + 8 π x e D y e D z e D · n = 1 p = 1 cos ( v n y D ) cos ( w p z D ) H - 2 D H - 3 D ( s + v n 2 + w p 2 / L D 2 ) + 16 π x e D y e D z e D · m = 1 n = 1 p = 1 cos ( v n y D ) cos ( w p z D ) cos ( u m x D ) · H - 1 D H - 2 D H - 3 D s + u m 2 + v n 2 + w p 2 / L D 2 . Applying (17b) and following equation (26) 2 cos v n c y D cos v n w y D = cos v n c y D - w y D + cos v n c y D + w y D = cos n π y e D c y D - w y D + cos n π y e D c y D + w y D k = 1 cos k x k 2 + α 2 = π 2 α cosh α ( π - x ) sinh α π - 1 2 α 2 we can obtain (27) n = 1 2 cos v n y D cos v n c y D s + v n 2 = y e D 2 s cosh s y e D - y D - c y D + cosh s y e D - y D + c y D · sinh s y e D - 1 - 1 s . Using the same method, the following formulas can be written as (28) n = 1 2 cos v n y D cos v n c y D s + u m 2 + v n 2 = y e D 2 ε m cosh ε m y e D - y D - c y D + cosh ε m y e D - y D + c y D · sinh ε m y e D - 1 - 1 ε m 2 p = 1 2 cos v n y D cos v n c y D s + v n 2 + w p 2 / L D 2 = y e D 2 ε p cosh ε p y e D - y D - c y D + cosh ε p y e D - y D + c y D · sinh ε p y e D - 1 - 1 ε p 2 p = 1 2 cos v n y D cos v n c y D s + u m 2 + v n 2 + w p 2 / L D 2 = y e D 2 ε m p cosh ε m p y e D - y D - c y D + cosh ε m p y e D - y D + c y D · sinh ε m p y e D - 1 - 1 ε m p 2 , where (29) ε m 2 = s + u m 2 = s + m 2 π 2 x e D 2 ε p 2 = s + w p 2 = s + p 2 π 2 L D 2 ε m p 2 = s + u m 2 + w p 2 = s + m 2 π 2 x e D 2 + p 2 π 2 L D 2 . Substitute (27)–(29) in (25) and simplify the equation is calculated as (30) s p ~ D = π x e D z e D · cosh s ( y e D - y D + c y D ) + cosh s ( y e D - y D - c y D ) · s sinh s y e D - 1 + 2 π x e D z e D m = 1 cos ( u m x D ) cos ( u m c x D ) sin ( u m w x D ) u m w x D × cosh ε m y e D - y D - y w D ε m sinh ε m y e D - 1 + cosh ε m y e D - y D + y w D · ε m sinh ε m y e D - 1 + 2 π x e D z e D p = 1 cos ( w p z D ) cos ( w p c z D ) sin ( w p w z D ) w p w z D × cosh ε p y e D - y D - y w D ε p sinh ε p y e D - 1 + cosh ε p y e D - y D + y w D · ε p sinh ε p y e D - 1 + 4 π x e D z e D m = 1 p = 1 cos ( w p z D ) cos ( u m x D ) · cos ( u m c x D ) sin ( u m w x D ) u m w x D cos ( w p c z D ) sin ( w p w z D ) w p w z D × y e D 2 cosh ε m p y e D - y D - y w D + cosh ε m p y e D - y D + y w D y e D 2 · ε m p sinh ε m p y e D - 1 .

Equation (30) is the mathematical model for pressure response of a partially penetrating hydraulic fracture in Laplace domain in dimensionless form. The solution in the real time domain can be obtained by using the inverse Laplace algorithm as proposed by Stehfest .

3. Validation of the Method

Kuchuk and Brighan  presented analytical solutions that are applicable to infinite-conductivity vertically fractured wells, elliptically shaped reservoirs, and anisotropic reservoirs producing at a constant rate or pressure. In order to validate the solution, we considered a special case that the fracture is full penetration; that is, w z D = 0.5 . We obtained some data from the literature presented by Kuchuk and Brighan. Figure 2 shows a comparison between the results from Kuchuk and Brighan and this work for the fully penetrating infinite-conductivity isotropic case. We can see a very good agreement between the solution in this paper and the literature, showing that the method in this study produces reliable transient pressure.

Model validation between this study and literature results.

4. Sensitivity Analysis

Based on the analytical solution for a partially penetrating fracture in a box-shaped reservoir presented in the previous part, a sensitivity study for the parameters affecting the pressure and pressure derivative in the model is carried out. The intention of this study is to show the effect of each of these parameters on the dynamic behavior of a partially penetrating fracture in a box-shaped reservoir. We evaluate the pressure transient solution by varying the values of four parameters including the fracture half height, the fracture half length, the fracture position, and the reservoir width. As shown on the plots, the pressure and pressure derivative have different shapes for each combination of fracture height, fracture length, fracture position, and reservoir width. Dimensionless basic parameters used for simulating pressure transient response are presented in Table 1.

Basic data of the system.

Dimensionless parameter Value
Reservoir length x e D 4000
Reservoir width y e D 4000
Reservoir height z e D 1
Half fracture length w x D 1
Half fracture height w z D 0.5
Variable L D 1
Fracture position c x D , c y D , c z D (2000, 2000, 0.5)
4.1. The Effect of Fracture Half Height and Off Center Fracture

Figure 3 depicts pressure and pressure derivative curves versus time for w z D = 0.005 , 0.025 , 0.05 , 0.1 , 0.3 , 0.5 with a fracture in the center of the reservoir, respectively (see Figure 4(a)). Other parameters are not changed in Table 1. Obviously, the pressure drop becomes larger as the fracture half height is decreased, which means that small fracture height will cause big pressure drop mainly in the early time period. The pressure drop for different w z D tends to be consistent as time goes on. As shown in the pressure derivative curves, the fracture height mainly influences the early linear flow and transition flow and has no effect on the intermediate radial flow and boundary dominated flow. The fluids which take place in the direction of the upper and lower boundaries towards the fracture because of the effect of the partially penetrating fracture could produce the transition flow. As shown in Figure 3, when the w z D = 0.5 (fully penetrating fracture), the transition flow cannot be seen from the pressure derivative curve. The end time of the early linear flow of the smaller w z D is shorter than that of larger w z D . All pressure derivative curves for different w z D value are also parallel in early linear flow regime.

The effect of fracture height for fracture in the center.

Schematic diagram of partially penetrating fracture.

Figure 5 depicts pressure and pressure derivative curves versus time for w z D = 0.005 , 0.025 , 0.05 , 0.1 , 0.3 , 0.5 with a fracture in the off center of the reservoir, respectively (see Figure 4(b)). The fracture is located at ( 500,500,0.5 ) and other parameters are not changed as shown in Table 1. Comparing to the fracture in the center of the reservoir, the only difference is the number of the boundary dominated flows. The fluids flowing from the nearer boundaries and further boundaries towards the fracture cause first boundary dominated flow and second boundary dominated flow, respectively, because the distance of the off center fracture to each boundary ( x -direction boundary and y -direction boundary) is different at late time. According to the boundary dominated flow which occurs twice as seen from the pressure derivative curve we can judge the fracture is off the center.

The effect of fracture height for fracture not in the center.

4.2. The Effect of Fracture Half Length and Off Center Fracture 4.2.1. Small Half Penetration Ratio (<inline-formula> <mml:math xmlns:mml="http://www.w3.org/1998/Math/MathML" id="M91"> <mml:mn>2</mml:mn> <mml:msub> <mml:mrow> <mml:mi>w</mml:mi></mml:mrow> <mml:mrow> <mml:mi>z</mml:mi> <mml:mi>D</mml:mi></mml:mrow> </mml:msub> <mml:mo><</mml:mo> <mml:mn>0.5</mml:mn></mml:math> </inline-formula>)

Figure 6 shows the type curves for different value of fracture half length ( w x D = 2 , 4 , 6,8 , resp.). The fracture is in the center of the reservoir while remaining other parameters are unchanged as shown in Table 1. As expected, the smaller the fracture half length, the higher the dimensionless pressure drop, which implies that small fracture length will cause great pressure drop at the early time. As shown in the pressure derivative curves, the fracture length mainly influences the early linear flow and transition flow and has no effect on the radial flow and boundary dominated flow. Comparing with the type curves for a fully penetrating fracture, the pressure derivative of a partially penetrating fracture has higher values during early time period. Before the intermediate radial flow regime, the pressure derivative becomes larger when the fracture length ( w x D ) is decreased. For the same fracture height and reservoir thickness, the larger the dimensionless fracture half length w x D is, the longer it takes to reach radial flow regime in the reservoir.

The effect of fracture length at w z D = 0.05 for fracture in the center.

Figure 7 depicts pressure and pressure derivative curves versus time for w x D = 2 , 4 , 6,8 with a fracture in the off center of the reservoir, respectively. The fracture is located at ( 500,500,0.5 ) and other parameters are not changed as shown in Table 1. Comparing to Figure 6, the off center fracture mainly affects the boundary dominated flow. The boundary dominated flow regime appears twice followed by the intermediate radial flow.

The effect of fracture length at w z D = 0.05 for fracture not in the center.

4.2.2. Large Half Penetration Ratio (<inline-formula> <mml:math xmlns:mml="http://www.w3.org/1998/Math/MathML" id="M99"> <mml:mn>2</mml:mn> <mml:msub> <mml:mrow> <mml:mi>w</mml:mi></mml:mrow> <mml:mrow> <mml:mi>z</mml:mi> <mml:mi>D</mml:mi></mml:mrow> </mml:msub> <mml:mo>></mml:mo> <mml:mn>0.5</mml:mn></mml:math> </inline-formula>)

The effect of the fracture half length on pressure and pressure derivative when the fracture with large half penetration ratio is in the center of the reservoir is shown in Figure 8. Because of the large half penetration ratio, the pressure behavior in this case tends to be similar to the fully penetrating fractures ( w z D = 0.5 ) where other factors such as fracture dimension have the main influence. A slight transition regime appears at the initial production time followed by the early linear flow regime. Comparing with the type curves for a fully penetrating fracture, the pressure derivative of a partially penetrating fracture has higher values during early time period. The pressure drop is larger as the fracture length is decreased and the pressure derivative has the same rule before the radial flow regime.

The effect of fracture length at w z D = 0.35 for fracture in the center.

Figure 9 depicts pressure and pressure derivative curves for w x D = 2 , 4 , 6,8 with a fracture in the off center of the reservoir, respectively. The position of the fracture is ( c x D = 500 , c y D = 500 , c z D = 0.5 ), and other parameters are not changed as shown in the Table 1. We notice that the pressure and pressure derivative values for the case of partially penetrating fractures in the off center of the reservoir are very similar to that case of fully penetrating fractures. The only difference is that the boundary dominated flow regime appears twice. As such, the boundary dominated flow can be used to distinguish whether the fracture in the center of the reservoir.

The effect of fracture length at w z D = 0.35 for fracture not in the center.

4.3. The Effect of the Reservoir Width

Figure 10 depicts pressure derivative curves versus time for y e D = 500 , 1500 , 2500 , 3500 with a fracture in the center of the reservoir, respectively, while other parameters are not changed. Reservoir width mainly affects the boundary dominated flow regime. As seen in Figure 10, the starting time of the boundary dominated flow regime is affected by the dimensionless reservoir width. It is observed that the dimensionless pressure drop becomes larger as the dimensionless reservoir width is decreased, which means that a small reservoir will cause big pressure drop in the boundary dominated flow regime.

The effect of reservoir width.

5. Application of Type Curve Matching

Type-curve matching is a quick method to estimate reservoir and fracture parameters. The following procedures illustrate how type curve matching is used to calculate reservoir and fracture characteristics such as permeability, fracture half length, and fracture half height.

Step 1.

Plot pressure change ( Δ p ) and pressure derivative ( t × Δ p ) values versus test time on a log-log graph.

Step 2.

Obtain the best match of the data with one of the type curves.

Step 3.

Read from an match point: t M , t D M , Δ p M , p D M , w z D , w x D , L D .

Step 4.

Calculate k h : (31) k h = 141.2 Q B μ p D z e Δ p .

Step 5.

Calculate L : (32) L = 0.0002637 t M k h ϕ μ c t t D M .

Step 6.

Calculate k z : (33) k z = k h L D L / z e 2 .

Step 7.

Calculate the fracture half height: (34) w z = w z D z e .

Step 8.

Calculate the fracture half length: (35) w x = w x D L .

Example 1.

Giving the reservoir and well data, (36) Q = 500 STB / D ϕ = 0.3 μ = 4 cp B o = 1.4 bbl / STB z e = 100 ft c t = 4 × 1 0 - 6 ps i - 1 r w = 0.25 ft p i = 6000 psi . Fracture position is in the center of the reservoir.

Step 1.

Plot pressure change ( Δ p ) and pressure derivative ( t × Δ p ) values versus test time on a log-log graph as shown in Figure 11.

Pressure and pressure derivative plot for example.

Step 2.

Obtain the best match of the data with one of the type curves as shown in Figure 12.

Type-curve matching plot for example ( w x D = 4 , L D = 1 ).

Step 3.

Read from an match point: t M , t D M , Δ p M , p D M , w z D , w x D , L D : (37) t M = 10 t D M = 0.11 Δ p M = 100 p D M = 0.05 w z D = 0.1 w x D = 4 L D = 1 .

Step 4.

Calculate k h from (31): (38) k h = 141.2 × 500 × 1.4 × 4 × 0.05 100 × 100 = 2 md .

Step 5.

Calculate L from (32): (39) L = 0.0002637 × 10 × 2 0.3 × 4 × 4 × 1 0 - 6 × 0.11 = 100 ft .

Step 6.

Calculate k z from (33): (40) k z = 2 ( 100 × 1 ) / 100 2 = 2 md .

Step 7.

Calculate the fracture half height from (34): (41) w z = 0.1 × 100 = 10 ft .

Step 8.

Calculate the fracture half length from (35): (42) w x = 4 × 100 = 400 ft . Table 2 compares the input data and the resulting values of the example.

Results of example.

Parameter Input value Calculated value by type curve matching technique
Horizontal permeability k h , md 2 2
Vertical permeability k z , md 2 2
Fracture half length w x , ft 400 400
Fracture half height w z , ft 10 10
6. Conclusions

A detailed step by step procedure for solving the analytical solution of a partially penetrating hydraulic fracture in a box-shaped reservoir by using Fourier cosine transform and Laplace transform is presented. The solution can be used to investigate the pressure transient behavior. In this paper, we validated it available with the published analytical solution for a relative simple system. Sensitivity analyses about the effects of the main parameters including fracture height, fracture length, and reservoir width on type curves are also presented in detail. Moreover the effect of the vertical position of the fracture on the pressure and pressure derivative is fully investigated. And an example is used to illustrate that the type curves can be used to analyze transient well test analysis for partially penetrating fracture in closed reservoirs. The merit of the solution is that it can also reduce the amount of computation and compute efficiently and quickly. The solution can be further developed as its great applicability.

Conflict of Interests

The authors declare that there is no conflict of interests regarding the publication of this paper.

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