CN107133393B - Passage pressure break well and story selecting and dynamic parameter optimum design method - Google Patents
Passage pressure break well and story selecting and dynamic parameter optimum design method Download PDFInfo
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Abstract
The present invention provides a kind of passage pressure break well and story selecting and dynamic parameter optimum design method, including：Collect the stratum geologic information of target well；Establish passage pressure break well and story selecting model；It is proposed passage pressure break feasibility judgment criterion；According to well and story selecting model, geologic information and the feasible property coefficient of passage pressure break of proppant physical parameter calculating target well are utilized；According to feasibility criterion, the passage pressure break feasibility of target well is judged；Established based on technology characteristics and add contacting between sand fluid column, middle top fluid column and proppant distribution；Rational proportion of the middle top time with adding the sand time is provided, so that Optimum Fracturing technique.The passage pressure break well and story selecting and dynamic parameter optimum design method select well model by what passage pressure break was included in the influence of the factors such as proppant, to judge that the pressure break compatibility of the passage pressure break feasibility of target well and target well and proppant provides foundation, the optimization to pressure break pulse distance then ensure that the high baffling characteristics of passage fracturing technology.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas development, in particular to a channel fracturing well selection layer selection and dynamic parameter optimization design method.
Background
In the proppant pack of conventional fracturing methods, the proppant particles all contact each other and fluid flow is confined to the pores between the proppant particles. The high-speed Channel Fracturing technology (high Channel Fracturing) is a new process technology designed, developed and introduced in 2010 by schrenberger company, and the technology establishes an open Channel network through uneven laying of proppant, so that the flow conductivity is not influenced by the permeability of the proppant, oil and gas enter a wellbore through a high flow conductivity Channel without passing through a filling layer, and the proppant is used as a flow conductivity medium in a discontinuous proppant filling layer to prevent the fracture of the surrounding Channel walls. The high-flow-guide channel fracturing adopts the addition of fiber fracturing fluid or self-polymerization proppant and combines a pulse type sand adding process to realize that proppant clusters are distributed at a certain interval in the fracture, the fracture is changed from 'surface' support to 'point' support, an open network channel is realized, the effective fracture length is improved, and the using amount of the proppant and the fracturing fluid is reduced.
Compared with the traditional fracturing technology, the high-speed channel fracturing has obvious advantages. The fracture flow conductivity is fundamentally changed, so that the fracture flow conductivity has better fracturing fluid flowback capability (the injury in the fracture is reduced), the pressure loss of the fracture is smaller (the manual lifting cost is reduced), a longer effective half-length of the fracture is obtained, the using amount of clear water and a propping agent is reduced, and the application range is wider. With the advent of channel fracturing technology, the process design and parameter optimization of the channel fracturing technology are receiving increasing attention. Therefore, a novel channel fracturing well selection layer selection and dynamic parameter optimization design method is invented.
Disclosure of Invention
The invention aims to provide a channel fracturing well selection layer and a dynamic parameter optimization design method for realizing optimization design of a channel fracturing technology by correcting a Halliburton channel fracturing well selection layer model and an application criterion and searching for a connection between a pulse slug ratio and a channel sand laying ratio.
The object of the invention can be achieved by the following technical measures: the method for optimizing and designing the well selection and the dynamic parameters of the channel fracturing comprises the following steps: step 1, collecting stratum geological data of a target well; step 2, establishing a channel fracturing well selection layer selection model; step 3, providing a channel fracturing feasibility judgment criterion; step 4, calculating a channel fracturing feasibility coefficient of the target well by using geological data and physical property parameters of the propping agent according to the well selection and stratum selection model; step 5, judging the channel fracturing feasibility of the target well according to the feasibility criterion; step 6, establishing a relation between the sand-adding liquid column, the middle top liquid column and the proppant distribution based on the process characteristics; and 7, giving a reasonable ratio of the middle top time to the sand adding time, thereby optimizing the fracturing process.
The object of the invention can also be achieved by the following technical measures:
in step 1, a channel is primarily selected to fracture a target well, and stratum geological data of the target well is collected.
In step 1, the collected geological data of the target well is geological data of each target well and physical parameters of the used propping agent, including closing pressure, ground stress, rock elastic modulus, rock poisson ratio, propping agent poisson ratio, seam width and ceramsite.
In step 2, the influence factors of the closing pressure, the formation elastic modulus, the proppant elastic modulus and the proppant arrangement mode are considered, and the channel fracturing well selection layer model is corrected.
In step 2, the established channel fracturing well selection layer model is as follows:
wherein Ratio' is a corrected channel fracturing feasibility coefficient and is dimensionless; v. of 1 The Poisson's ratio of rock is dimensionless; e 1 Is rock elastic modulus, MPa; v. of g The Poisson's ratio of a proppant filling layer is dimensionless; v. of 2 Is proppant poisson ratio, dimensionless; e 2 Is the proppant elastic modulus, MPa; r is the particle size of the proppant particle, m; k is a radical of t Is a permutation pattern factor without dimension; sigma is the ground stress, MPa; sigma h The fracture closure stress is MPa.
In step 3, all arrangement modes of the proppant are comprehensively considered, and the corrected channel fracturing feasibility judgment criterion is determined on the basis of the channel fracturing application criterion.
In step 3, the determined corrected channel fracturing feasibility judgment criterion is as follows:
ratio' >320: the geomechanics property is good, and the method is more suitable for channel fracturing;
220 < Ratio' < 320: the geomechanical property is general, and channel fracturing can be carried out;
ratio' <220: the geomechanical property is poor, and channel fracturing cannot be carried out;
wherein, the Ratio' is a corrected channel fracturing feasibility coefficient and has no dimension.
And 4, substituting the parameters of geological data and physical properties of the propping agent into the corrected channel fracturing well selection layer model, and calculating the channel fracturing feasibility coefficient of the target well.
In step 5, comparing the obtained target well channel fracturing feasibility coefficient range with the corrected channel fracturing application criterion, and judging the channel fracturing feasibility of the target well.
In step 6, according to the process characteristics of channel fracturing, the sand adding fluid and the displacing fluid are circularly injected into the well in a certain proportion of liquid discharge time, and assuming that the proppant filling layer is square, H p The length of the filling layer, H is the length of the crack surface supported by the filling layer, L p The filling layer width, L the width of the crack surface supported by the filling layer, and the side length proportional relation between the filling layer and the supporting crack surface isSo as to establish a sand-adding liquid column, a middle top liquid column and R s1 The relation between them, i.e. within a slug period, the middle top timet L And sand adding time t D The displacement liquid column L and the sand adding liquid column D have the following relations:
wherein, t D The sand adding time in the slug period, h; t is t L The middle top time in the slug period, h; d is the length of the sand liquid column added in the slug period, m; l is the length of the displacement liquid column m in the slug period;and no dimension is required.
In step 7, according to the performance of the dimensionless diversion capacity under different widths of the proppant filling layer, the reasonable proportion of the middle-top time and the sand adding time is optimized, the optimal time ratio range is determined to be [1,5], and the fracturing process is optimized on the basis.
According to the channel fracturing well selection layer and dynamic parameter optimization design method, the optimized design of the channel fracturing technology is realized by correcting the Halliburton channel fracturing well selection layer model and the application criterion and searching the relation between the pulse slug ratio and the channel sand laying ratio. The corrected channel fracturing well selection layer selection model and the application criterion consider the influences of factors such as closing pressure, elastic modulus of a propping agent, arrangement mode of the propping agent and the like, and provide a more comprehensive basis for solving the channel fracturing feasibility of a target well and the fracturing compatibility of the target well and the propping agent. Meanwhile, based on the process characteristics of channel fracturing, the established relation between the pulse slug ratio and the channel sand laying ratio is used for searching the optimal pulse slug ratio, so that the sand adding time and the middle-top time can be correspondingly adjusted according to the actual pulse period, and the high flow guide characteristic of the fracturing process is ensured. According to the channel fracturing well selection layer and dynamic parameter optimization design method, the influence of factors such as closing pressure, elastic modulus of a propping agent, arrangement mode of the propping agent and the like is considered in a corrected channel fracturing well selection layer model, and more comprehensive understanding is provided for understanding channel fracturing feasibility of a target well and fracturing compatibility of the target well and the propping agent. The corrected channel fracturing application criterion comprehensively considers the arrangement mode of the propping agents, and the randomness of the arrangement mode of the propping agent particles in a large scale is described through the averaging of the arrangement type factors, so that the accuracy of the application criterion is ensured. The establishment of the channel fracturing flow conductivity analytic model provides a basis for analyzing the channel fracturing yield degree, and the pulse interval optimization on the basis can guide the optimization direction of the fracturing process.
Drawings
FIG. 1 is a flow chart of an embodiment of a method for well selection and dynamic parameter optimization design by channel fracturing according to the present invention;
FIG. 2 is a schematic view of a conventional particle arrangement in one embodiment of the present invention;
FIG. 3 is a schematic illustration of the relationship between the sanding fluid column, the middle top fluid column, and the proppant distribution in an embodiment of the present invention;
FIG. 4 is a schematic diagram of a proppant pack distribution ratio in accordance with an embodiment of the present invention;
FIG. 5 is a graph illustrating the behavior of dimensionless conductivity as the width of the fill layer increases in accordance with an embodiment of the present invention.
Detailed Description
In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.
As shown in fig. 1, fig. 1 is a flow chart of a channel fracturing well selection and dynamic parameter optimization design method of the present invention.
At step 101, stratigraphic geological data of a target well is gathered. And primarily selecting a channel to fracture the target well, and collecting the stratum geological data of the target well. Through screening statistics, geological data of each target well and physical property parameters of the used propping agents are listed in the following table.
TABLE 1 geological data of each target well and physical parameters of proppant used
In step 102, a channel fracturing well selection layer model is established. And (4) correcting the Halliburton channel fracturing well selection layer model by considering influence factors such as closing pressure, formation elastic modulus, proppant arrangement mode and the like.
The channel fracturing well selection layer model used by Halliburton is
Wherein Ratio is a channel fracturing feasibility coefficient and is dimensionless; e is the elastic modulus of stratum rock, MPa; sigma h The fracture closure stress is MPa.
As can be seen from the above formula, the well selection layer model only considers the influence of the rock on the channel fracturing, and does not consider the proppant-related factors. The invention takes into account the equivalent elastic modulus of the rock and the proppant filling layer to replace the elastic modulus of the rock in the formula, and corrects the model, namely
Wherein Ratio' is a corrected channel fracturing feasibility coefficient and is dimensionless; e * Is the equivalent elastic modulus, MPa, of rock and proppant. Equivalent modulus of elasticity E of rock and proppant * Can be expressed as
Wherein E is * Equivalent modulus of elasticity, MPa; v. of 1 The Poisson's ratio of rock is dimensionless; e 1 Is rock elastic modulus, MPa; v. of g Is the poisson ratio of a proppant filling layer (which can be equivalent to the poisson ratio of proppant particles), and is dimensionless; e g The elastic modulus of the proppant filling layer is MPa. Modulus of elasticity E of proppant pack g Can be expressed as
Wherein v is 2 Is the proppant poisson ratio, dimensionless; e 2 Is the proppant elastic modulus, MPa; r is the particle size of the proppant particle, m; k is a radical of t Is a permutation pattern factor without dimension; σ is the ground stress, MPa.
Thus, the modified well selection layer model can be expressed as
In step 103, a channel fracture feasibility judgment criterion is provided. And comprehensively considering all arrangement modes of the proppant, and determining a corrected channel fracturing feasibility judgment criterion on the basis of the Halliburton channel fracturing application criterion.
There are 5 common particle alignment patterns, as shown in FIG. 2. The influence degree of each arrangement mode on the well selection layer selection model is shown in the formula (7) by arrangement mode factors k with different sizes t Is shown (see table 2). In the large-scale environment of hydraulic fracturing, the occurrence probability of the 5 particle arrangement modes is considered to be the same, so that the influence degree of each arrangement mode can be weighted equally, and k in the formula (7) t Average of 5 permutation pattern factors
TABLE 2 different permutations and corresponding mode factors
The Halliburton channel fracturing application criteria are as follows:
Ratio>R 2 : the geomechanics property is good, and the method is more suitable for channel fracturing;
R 1 ≤Ratio≤R 2 : the geomechanical property is general, and channel fracturing can be carried out;
Ratio<R 1 : the geomechanical property is poor, and channel fracturing cannot be carried out. For R 1 ,R 2 Having R 1 ＝350,R 2 ＝500。
Since the Halliburton channel fracturing application guidelines do not take into account the arrangement of the proppant in the fracture, they are considered to be applicable to the most common simple cubic arrangement mode. Then, the following relationship exists between the criterion and the correction criterion according to equations (3) and (4):
wherein the content of the first and second substances,arranging the arithmetic mean value of the mode factors for different arrangement modes without dimension; k is a radical of formula 1 The array mode factor is an array mode factor of a simple cube array mode and has no dimension; r 1 ，R 2 The method is a feasibility coefficient of Halliburton channel fracturing applicable criteria, and has no dimension; r 1 '，R 2 ' is a feasibility coefficient of the correction criterion, dimensionless.
Corrected R is obtained through calculation 1 ',R 2 ' then the corrected channel fracture applicability criterion can be expressed as
Ratio' >320: the geomechanics property is good, and the method is more suitable for channel fracturing;
ratio' is more than or equal to 220 and less than or equal to 320: the geomechanical property is general, and channel fracturing can be carried out;
ratio' <220: the geomechanical property is poor, and channel fracturing cannot be carried out.
In step 104, according to the well selection and stratum selection model, the channel fracturing feasibility coefficient of the target well is calculated by using geological data and physical property parameters of the propping agent. And substituting the geological data, the physical property of the propping agent and other parameters into the corrected channel fracturing well selection layer selection model, and calculating the channel fracturing feasibility coefficient of the target well.
The parameters in Table 1 were calculated by substituting the formula (7) and the calculation was still performedThe resulting channel fracture feasibility coefficient ranges for each target well are shown in table 3.
TABLE 3 original channel fracturing feasibility coefficients and corrected channel fracturing feasibility coefficients
In step 105, channel fracture feasibility of the target well is determined according to feasibility criteria. And comparing the obtained target well channel fracturing feasibility coefficient range with the corrected channel fracturing application criterion, and judging the channel fracturing feasibility of the target well.
Comparing the channel fracturing feasibility coefficients obtained in the table 2 with the corrected channel fracturing application criteria, the reclamation slope 125 and the pseudo-classic 271 can be used for carrying out channel fracturing wells. Because the consideration of the revised model and criteria to the channel fracture factors is still limited, the use of revised applicability criteria still needs to be established on a broad practical basis and continuously updated in practice.
At step 106, a link between the sanding fluid column, the middle top fluid column, and the proppant distribution is established based on the process characteristics. For a target well which can be fractured by a channel, establishing a relation between the sand adding liquid column, the middle top liquid column and the proppant distribution based on the process characteristics.
According to the process characteristics of channel fracturing, the sand adding liquid and the displacing liquid are circularly injected into the well in a certain proportion of liquid discharge time, and a sand pile and a diversion channel shown in figure 3 are formed in the fracture. As shown in FIG. 4, assume the proppant pack is square, H p The length of the filling layer, H is the length of the crack surface supported by the filling layer, L p The filling layer width, L the width of the crack surface supported by the filling layer, and the side length proportional relation between the filling layer and the supporting crack surface isAnd for ease of discussion, take the ideal case R s1 ＝R s2 Then a sand-adding liquid column, a middle top liquid column and R can be established s1 The relation between, i.e. within a slug period, the middle top time t L And sand adding time t D The displacement liquid column L and the sand adding liquid column D have the following relations:
wherein, t D The sand adding time in the slug period, h; t is t L The middle top time in the slug period, h; d is the length of the sand liquid column added in the slug period, m; l is the displacement liquid column length m in the section plug period.
At step 107, a reasonable ratio of the top-in-middle time to the sanding time is given to optimize the fracturing process. And optimizing the reasonable proportion of the top time and the sand adding time by utilizing the dimensionless flow conductivity optimization, thereby optimizing the fracturing process.
In order to more visually reflect the influence of the channel sand laying ratio on the channel fracturing flow conductivity, a flow conductivity analysis model of channel fracturing needs to be established, and the ratio of the top time to the sand adding time is optimized according to the flow conductivity analysis model. As shown in FIG. 4, the equivalent permeabilities of zones 1 and 2 are related to the permeabilities of zones 1 and 2, respectively
Wherein the content of the first and second substances,equivalent Permeability, μm, for zones 1, 2 2 ；k 1 Permeability of zone 1, μm 2 ；k 2 Permeability of region 2, μm 2 。
Considering region 3 on this basis, the equivalent permeability of regions 1, 2, 3 is
Wherein, the first and the second end of the pipe are connected with each other,equivalent Permeability, μm, for zones 1, 2, 3 2 ；k 3 Permeability of region 3, μm 2 。
The permeability of region 2 can be determined by the Kozeny-Carmen empirical formula
Wherein C is a K-C constant, often C =5; phi is porosity, dimensionless; d is the proppant particle diameter, μm.
The permeability of zone 1 and zone 3 can be expressed as
Wherein, w f The width of the crack closure, μm.
The conductivity of the channel fractures is then
Wherein, F cH In order to increase the flow conductivity of the channel fracturing fracture 3 。
To avoid loss of generality, the conductivity is now dimensionless, and pulse intervals are explored by using dimensionless conductivity. Dimensionless conductivity is defined as the ratio of the fracture conductivity of a channel to the ideal conductivity without proppant at the same closure gap width, i.e.
Wherein f is dimensionless flow conductivity and dimensionless; f c The ideal flow conductivity of the proppant-free material under the same width of the closed seam is micron 3 Can be represented as
Therefore, the dimensionless flow conductivity of different flow channel sizes can be calculated by combining the equivalent permeability of channel fracturing and the width of a closed crack.
The results of the dimensionless air guide capacity calculation are shown in fig. 5. In FIG. 5, with R s1 Increase of (d), dimensionless conductivity increasing first and then decreasing, and at R s1 Maximum value is taken at = 0.16. Thus, R can be substituted s1 The range is given as [0.16,0.5]So as to ensure the high flow guiding characteristic of channel fracturing.
According to formula (9) from R s1 The optimal value range of the displacement liquid can determine the optimal time ratio of the displacement liquid to the sand adding liquid in one slug period, namely [1,5]. Thus, the pulse times of the sanding fluid and the displacement fluid are determined based on the actual slug period based on the optimal time ratio, and further adjustments to the fracturing process can then be made.
According to the channel fracturing well selection layer and dynamic parameter optimization design method, the influence of factors such as the propping agent is brought into the well selection model of channel fracturing, a basis is provided for judging the channel fracturing feasibility of a target well and the fracturing compatibility of the target well and the propping agent, and the high flow conductivity of a channel fracturing process is ensured by optimizing the fracturing pulse interval.
Claims (11)
1. The method for optimally designing the channel fracturing well selection layer and the dynamic parameters is characterized by comprising the following steps of:
step 1, collecting stratum geological data of a target well;
step 2, establishing a channel fracturing well selection layer selection model;
step 3, providing a channel fracturing feasibility judgment criterion;
step 4, calculating a channel fracturing feasibility coefficient of the target well by using geological data and physical property parameters of the propping agent according to the well selection and stratum selection model;
step 5, judging the channel fracturing feasibility of the target well according to the feasibility judgment criterion;
step 6, establishing a relation between the sand-adding liquid column, the middle top liquid column and the proppant distribution based on the process characteristics;
and 7, giving a reasonable ratio of the middle top time to the sand adding time, thereby optimizing the fracturing process.
2. The method for well selection and dynamic parameter optimization design through channel fracturing, as claimed in claim 1, wherein in step 1, a target well is initially selected through channel fracturing, and geological information of the stratum of the target well is collected.
3. The method for optimizing and designing the well selection and dynamic parameters through channel fracturing as claimed in claim 2, wherein in the step 1, the collected geological data of the stratum of the target well are geological data of each target well and physical parameters of a used propping agent, including closing pressure, ground stress, rock elastic modulus, rock poisson ratio, propping agent poisson ratio, seam width and ceramsite.
4. The method for optimizing and designing the well selection and the dynamic parameters of the channel fracturing as claimed in claim 1, wherein in the step 2, the model of the well selection and the channel fracturing is corrected by considering the influence factors of the closing pressure, the elastic modulus of the stratum, the elastic modulus of the proppant and the arrangement mode of the proppant.
5. The channel fracturing well selection and dynamic parameter optimization design method of claim 1, wherein in step 2, the established channel fracturing well selection model is:
wherein Ratio' is a corrected channel fracturing feasibility coefficient and is dimensionless; v. of 1 The Poisson ratio of the rock is dimensionless; e 1 Rock modulus of elasticity, MPa; v. of g Is the Poisson's ratio of a proppant filling layer, and is dimensionless; v. of 2 Is the proppant poisson ratio, dimensionless; e 2 Is the proppant elastic modulus, MPa; r is the particle size of the proppant particle, m; k is a radical of t Is a permutation pattern factor without dimension; sigma is the ground stress, MPa; sigma h Fracture closure stress, MPa.
6. The method for well selection and dynamic parameter optimization design for channel fracturing of claim 1, wherein in step 3, each arrangement mode of proppant is comprehensively considered, and a corrected channel fracturing feasibility judgment criterion is determined on the basis of a channel fracturing applicability criterion.
7. The channel fracturing well selection and dynamic parameter optimization design method of claim 6, wherein in step 3, the determined revised channel fracturing feasibility judgment criterion is:
ratio' >320: the geomechanics property is good, and the method is more suitable for channel fracturing;
220 < Ratio' < 320: the geomechanical property is general, and channel fracturing can be carried out;
ratio' <220: the geomechanical property is poor, and channel fracturing cannot be carried out;
wherein Ratio' is a corrected channel fracturing feasibility coefficient and is dimensionless.
8. The channel fracturing well selection and dynamic parameter optimization design method of claim 4, wherein in step 4, the parameters of geological data and proppant physical properties are substituted into the corrected channel fracturing well selection model to calculate the channel fracturing feasibility coefficient of the target well.
9. The channel fracturing well selection and dynamic parameter optimization design method of claim 6, wherein in step 5, the obtained channel fracturing feasibility coefficient range of the target well is compared with the corrected channel fracturing feasibility judgment criterion to judge the channel fracturing feasibility of the target well.
10. The method for selecting a well and designing a dynamic parameter through channel fracturing as claimed in claim 1, wherein in step 6, according to the process characteristics of channel fracturing, the sand-adding fluid and the displacing fluid are cyclically injected into the well in a certain proportion of drainage time, assuming that the proppant pack is square and H is H p The length of the filling layer, H is the length of the crack surface supported by the filling layer, L p The width of the filling layer, L the width of the crack surface supported by the filling layer, and the side length proportional relation between the filling layer and the supporting crack surface isSo as to establish a sand-adding liquid column, a middle top liquid column and R s1 The relation between, i.e. within a slug period, the middle top time t L And the sand adding time t D The displacement liquid column L and the sand adding liquid column D have the following relations:
wherein, t D The sand adding time in the slug period, h; t is t L The middle top time in the slug period, h; d is the length of the sand liquid column added in the slug period, m; l is the displacement liquid column length m in the slug period;and no dimension is required.
11. The method for the optimal design of the well selection layer and the dynamic parameters of the channel fracturing, which is described in claim 1, is characterized in that in step 7, the optimal time ratio range is determined to be [1,5] according to the performance of the dimensionless flow conductivity under different widths of the proppant filling layer, and the reasonable proportion of the middle top time and the sand adding time is optimized, and the fracturing process is optimized on the basis.
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