CN112182992A - Tight sandstone gas reservoir horizontal well staged fracturing fracture position optimization method - Google Patents
Tight sandstone gas reservoir horizontal well staged fracturing fracture position optimization method Download PDFInfo
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Abstract
A tight sandstone gas reservoir horizontal well staged fracturing fracture position optimizing method provides a tight sandstone gas reservoir horizontal well staged fracturing fracture position optimizing process which comprises horizontal well staged fracturing fracture position optimizing and fracture parameter optimizing, wherein the horizontal well staged fracturing fracture position optimizing is based on a predominant production potential evaluation method of grid data, and the fracture parameter optimizing utilizes response surface multi-factor test design. The method provided by the invention simultaneously considers the coupling relation between the optimization of the fracture position and the multi-objective fracture parameter optimization, and the optimization result has more advantages for improving the absolute unobstructed flow at the initial stage of the gas reservoir.
Description
Technical Field
The invention belongs to the technical field of fracturing development and optimization of horizontal wells in gas reservoir engineering, and particularly relates to a staged fracturing fracture position optimization method for a tight sandstone gas reservoir horizontal well.
Background
The tight sandstone gas reservoir is generally a low-porosity and low-permeability reservoir, the natural productivity of a gas well is very low, and the economic benefit is difficult to generate in the conventional vertical well development, so that the exploitation is mostly carried out by adopting a horizontal well staged fracturing mode. The horizontal well fracturing optimization design is an important means for realizing efficient and economic exploitation of a gas well, and the yield of the fractured horizontal well is related to fracture parameters and fracture positions. However, the influence of fracture parameters on productivity is paid more attention to in the current horizontal well fracturing optimization, and besides the interference among multiple factors is not considered, the influence of the selection of the fracturing horizontal section position on the fracturing effect is rarely paid attention to.
Disclosure of Invention
In order to overcome the defects of the prior art, the invention aims to provide a method for optimizing the fracture position of the staged fracturing of the tight sandstone gas reservoir horizontal well, which optimizes the fracturing position of the horizontal stage by utilizing the advantageous production potential based on grid data, gives a response surface model of absolute unobstructed flow and fracture parameters after the gas reservoir is fractured by means of response surface multi-factor test design, and establishes an optimal flow of the fracturing fracture position of the tight sandstone gas reservoir horizontal well by integrating the optimal results of the fracturing position of the horizontal stage and the response surface model of the unobstructed flow. The preferred results are more advantageous for enhancing the initial recovery of tight sandstone gas reservoirs.
In order to achieve the purpose, the invention adopts the technical scheme that:
a method for optimizing a horizontal well staged fracturing fracture position of a tight sandstone gas reservoir is characterized by comprising the following steps of:
step 1, optimizing the fracture position of a horizontal well section;
establishing a fracturing horizontal well numerical simulation model, extracting dynamic and static grid data in the numerical simulation model, calculating the dominant production potential of a horizontal well region by using a formula (1), and determining favorable reservoir sections for fracturing transformation of the horizontal well according to the level of the production potential;
Jijk(t)＝[Sgijk(t)-Sgr]·[pgijk(t)-paba]·ln(Kijk-Kmin,ijk+1)·h·φ
(1)
in the formula, Jijk(t) is the dominant production potential of grid (i, j, k) at time t; sgijk(t) is the gas saturation, decimal, of the grid (i, j, k) at time t; sgrIrreducible gas saturation, decimal; p is a radical ofgijk(t) is the pressure, MPa, of the grid (i, j, k) at time t; p is a radical ofabaThe waste pressure of the gas reservoir is MPa; kijkReservoir permeability, mD, for grid (i, j, k); kmin,ijkMinimum reservoir permeability for a gas reservoir, mD; h is the reservoir effective thickness of the gas reservoir, m; phi is the average porosity, decimal, of the gas reservoir;
advantageous production potential prior to use requires dimensionless processing by the following formula (2):
in the formula (I), the compound is shown in the specification,
dimensionless dominant production potential for grid (i, j, k) at time t;
step 2, optimizing staged fracturing fracture parameters of the horizontal well;
adopting BBD optimal response surface Design in Design-expert test Design software, obtaining a response surface with higher precision by reasonably arranging the positions of test points and utilizing a small number of test points, wherein the response variable of the response surface test Design is the absolute unimpeded flow after the gas reservoir is fractured, and the variable factors are selected from the classes of fracture half-length, the number of the fracture, the fracture conductivity and the fracture spacingThe variable interval of the half length of the crack is 50-300 m, the variable interval of the number of the crack is 1-15, and the flow conductivity of the crack is 10-300 μm2Cm, the crack spacing is optimized by 5 types, namely equal spacing, increasing spacing, decreasing spacing, small end, medium end, large end, medium end, small end, medium end and small end;
step 3, optimizing and proposing the fracture position of the horizontal well staged fracturing;
and (3) giving a fracturing reservoir section with the optimal fracturing fracture position of the horizontal well section obtained in the step 1), and coupling the optimal fracture parameter combination determined by the unobstructed flow response surface model obtained in the step 2) to give a fracturing reservoir section and optimal fracture parameter optimal suggestion of the staged fracturing fracture position of the horizontal well of the tight sandstone gas reservoir.
The invention has the beneficial effects that:
compared with the traditional single-factor fracture parameter optimization result, the method provided by the invention has the advantages that the single-factor fracture parameter optimization result does not consider the interference among multiple factors, the traditional method does not consider the optimal fracture position, the coupling of the two is the method specifically provided by the invention, and the optimization result of the method can obtain higher absolute unimpeded flow for the staged fracturing of the compact gas reservoir horizontal well. The method can provide an optimization thought for staged fracturing design of the tight sandstone gas reservoir horizontal well, and has practical significance for improving staged fracturing effect of the tight sandstone gas reservoir horizontal well.
Drawings
FIG. 1 is a three-dimensional distribution diagram of log permeability of an L gas reservoir model;
FIG. 2 is a graphical representation of a planform of the advantageous production potential of X horizontal well zones (a) gas saturation, (b) permeability, and (c);
FIG. 3 is a three-dimensional response surface model between absolute unobstructed flow and fracture parameters.
Detailed Description
The technical solution of the present invention is described in detail below with reference to the accompanying drawings and examples.
A method for optimizing a horizontal well staged fracturing fracture position of a tight sandstone gas reservoir is characterized by comprising the following steps of:
step 1, optimizing the fracture position of a horizontal well section;
establishing a fracturing horizontal well numerical simulation model, extracting dynamic and static grid data in the numerical simulation model, calculating the dominant production potential of a horizontal well region by using a formula (1), and determining favorable reservoir sections for fracturing transformation of the horizontal well according to the level of the production potential;
Jijk(t)＝[Sgijk(t)-Sgr]·[pgijk(t)-paba]·ln(Kijk-Kmin,ijk+1)·h·φ (1)
in the formula, Jijk(t) is the dominant production potential of grid (i, j, k) at time t; sgijk(t) is the gas saturation, decimal, of the grid (i, j, k) at time t; sgrIrreducible gas saturation, decimal; p is a radical ofgijk(t) is the pressure, MPa, of the grid (i, j, k) at time t; p is a radical ofabaThe waste pressure of the gas reservoir is MPa; kijkReservoir permeability, mD, for grid (i, j, k); kmin,ijkMinimum reservoir permeability for a gas reservoir, mD; h is the reservoir effective thickness of the gas reservoir, m; phi is the average porosity, decimal, of the gas reservoir;
advantageous production potential prior to use requires dimensionless processing by the following formula (2):
in the formula (I), the compound is shown in the specification,
dimensionless dominant production potential for grid (i, j, k) at time t;
step 2, optimizing staged fracturing fracture parameters of the horizontal well;
in Design-expert experimental Design softwareThe BBD optimal response surface design is characterized in that a small number of test points are utilized to obtain a response surface with higher precision by reasonably arranging the positions of the test points, the response variable of the response surface test design is the absolute unobstructed flow after gas reservoir fracturing, variable factors are selected from the half length of a crack, the number of the crack, the flow conductivity of the crack and the type of the interval of the crack, wherein the variable interval of the half length of the crack is 50-300 m, the variable interval of the number of the crack is 1-15, and the flow conductivity of the crack is 10-300 mu m2Cm, the crack spacing is optimized by 5 types, namely equal spacing, increasing spacing, decreasing spacing, small end, medium end, large end, medium end, small end, medium end and small end;
step 3, optimizing and proposing the fracture position of the horizontal well staged fracturing;
and (3) giving a fracturing reservoir section with the optimal fracturing fracture position of the horizontal well section obtained in the step 1), and coupling the optimal fracture parameter combination determined by the unobstructed flow response surface model obtained in the step 2) to give a fracturing reservoir section and optimal fracture parameter optimal suggestion of the staged fracturing fracture position of the horizontal well of the tight sandstone gas reservoir.
Example (b):
the X horizontal well zone was located eastern in the deldos basin, the average permeability of the well zone was 0.34mD, the average porosity was 6.6%, the average gas saturation was 60.7%, and a typical tight sand gas reservoir. And establishing a gas reservoir horizontal well fracturing numerical simulation model according to the L gas reservoir description related data and the fluid high-pressure physical property data, wherein the model is a gas-water two-phase black oil model, and the grid number is 53 multiplied by 66 multiplied by 60. The three-dimensional distribution of the L gas reservoir model permeability is shown in figure 1.
As described in the patent claims method, in order to verify the reliability and advantages of the established method, the method is compared with a single-factor optimization result, and according to the single-factor optimization result, the longer the half-length of the crack is, the more the number of the crack is, the higher the flow conductivity is, and the best fracturing effect is achieved, but if the economic cost is considered, the more the number of the crack is, the better the crack is. The preferable suggestion and effect comparison of the fracture position of the X horizontal well staged fracturing is carried out by taking 8 fractures as an example.
As described in the patent claims method, the advantageous production potential of the X-well zone is plotted according to equations (1) and (2), which are collectively shown in fig. 2 for comparison with the conventional permeability field and gas saturation field. As can be seen from fig. 2, the gas saturation (fig. 2(a)) and permeability (fig. 2(b)) plane profiles do not well determine the reservoir section favorable for reconstruction, and it can be known from the gas saturation and permeability profiles that the favorable reconstruction position should be located at the toe of the horizontal well, i.e. the fracture interval type should be of the interval decreasing type, but it can be known from the preferential production potential diagram (fig. 2(c)) that the production potentials of the root and the toe of the horizontal well are both greater, so that the reservoir section favorable for fracture reconstruction of the horizontal well should be as close to the root and the toe as possible, and the interval between the two ends is appropriately smaller than the middle interval, i.e. the number of fracture strips is appropriately increased at the two ends, the fracture interval is reduced.
According to the method, Design-expert test Design software is used, BBD optimal response surface Design is adopted, 45 sets of combination schemes are selected from variable factors and response variables in the technical scheme 2, and numerical simulation is used for simulating the absolute unimpeded flow of the gas reservoir under different schemes in different stages. A three-dimensional response surface model between the absolute unobstructed flow and the fracture parameters was obtained by regression fitting using experimental design software (figure 3). The response surface model can be used to obtain the optimal fracture combination and the corresponding predicted gas reservoir unobstructed flow under different numbers of fractures, and in order to verify the accuracy of the model, table 1 gives the absolute unobstructed flow predicted by the model under 8 fractures and the absolute unobstructed flow calculated by actual numerical simulation. It can be seen from table 1 that the relative error between the prediction result and the actual calculation result is kept at about 5%, which proves that the established three-dimensional response surface model has certain reliability. The comparison table of the model prediction result and the actual calculation result in table 1 can also show that certain difference exists in the optimization effect between the multi-factor and the single factor, namely that the optimal parameter combination actually exists in the optimization effect of the fracture.
TABLE 1
As described in the patent claims method, in order to embody the advantages of the method provided by the invention and further verify the necessity of favorable reservoir section and multi-objective optimization coupling, table 2 shows the absolute unimpeded flow of the single-objective interval decrement (according to the cognition results of permeability and gas saturation) horizontal well fracture optimization results (initial scheme) and the optimization results (optimization scheme) of the invention. As can be seen from the comparison result table of the absolute unimpeded flow in different schemes in Table 2, the absolute unimpeded flow of the optimized scheme can be improved by 7.39% compared with the initial scheme. Therefore, there is a need in horizontal well staged fracturing design to simultaneously consider the coupling between the preference of the fracture location and the multi-factor optimization of fracture parameters.
TABLE 2
The above description is only an embodiment of the present method and is not intended to limit the scope of the present invention. Any equivalent changes and modifications that can be made by one skilled in the art without departing from the spirit and principles of the invention should fall within the protection scope of the invention.
Claims (1)
1. A method for optimizing a horizontal well staged fracturing fracture position of a tight sandstone gas reservoir is characterized by comprising the following steps of:
step 1, optimizing the fracture position of a horizontal well section;
establishing a fracturing horizontal well numerical simulation model, extracting dynamic and static grid data in the numerical simulation model, calculating the dominant production potential of a horizontal well region by using a formula (1), and determining favorable reservoir sections for fracturing transformation of the horizontal well according to the level of the production potential;
Jijk(t)＝[Sgijk(t)-Sgr]·[pgijk(t)-paba]·ln(Kijk-Kmin,ijk+1)·h·φ (1)
in the formula, Jijk(t) is the dominant production potential of grid (i, j, k) at time t; sgijk(t) is the gas saturation, decimal, of the grid (i, j, k) at time t; sgrIrreducible gas saturation, decimal; p is a radical ofgijk(t) is the pressure, MPa, of the grid (i, j, k) at time t; p is a radical ofabaThe waste pressure of the gas reservoir is MPa; kijkReservoir permeability, mD, for grid (i, j, k); kmin,ijkMinimum reservoir permeability for a gas reservoir, mD; h is the reservoir effective thickness of the gas reservoir, m; phi is the average porosity, decimal, of the gas reservoir;
advantageous production potential prior to use requires dimensionless processing by the following formula (2):
in the formula (I), the compound is shown in the specification,
dimensionless dominant production potential for grid (i, j, k) at time t;
step 2, optimizing staged fracturing fracture parameters of the horizontal well;
adopting BBD optimal response surface Design in Design-expert test Design software, obtaining a response surface with higher precision by reasonably arranging the positions of test points by using a small number of test points, wherein the response variable of the response surface test Design is the absolute unimpeded flow after gas reservoir fracturing, and the variable factors are selected from the group consisting of half-length of a crack, the number of the crack strips, the flow conductivity of the crack and the type of the crack spacing, wherein the variable interval of the half-length of the crack is 50-300 m, the variable interval of the number of the crack strips is 1-15, and the flow conductivity of the crack is 10-300 mu m2Cm, the crack spacing is optimized by 5 types, namely equal spacing, increasing spacing, decreasing spacing, small end, medium end, large end, medium end, small end, medium end and small end;
step 3, optimizing and proposing the fracture position of the horizontal well staged fracturing;
and (3) giving a fracturing reservoir section with the optimal fracturing fracture position of the horizontal well section obtained in the step 1), and coupling the optimal fracture parameter combination determined by the unobstructed flow response surface model obtained in the step 2) to give a fracturing reservoir section and optimal fracture parameter optimal suggestion of the staged fracturing fracture position of the horizontal well of the tight sandstone gas reservoir.
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| CN114676631A (en) * | 2022-03-25 | 2022-06-28 | 西南石油大学 | Shale gas reservoir fracturing horizontal well fracturing transformation parameter recommendation method |
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| WO2016192077A1 (en) * | 2015-06-04 | 2016-12-08 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Method for establishing and solving numerical well-testing model of horizontal well for tight gas hydraulic fracturing |
| CN107301306A (en) * | 2017-08-04 | 2017-10-27 | 中国石油化工股份有限公司华北油气分公司 | Dynamic open-flow capacity Forecasting Methodology for DAMAGE OF TIGHT SAND GAS RESERVOIRS pressure break horizontal well |
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| CN114676631A (en) * | 2022-03-25 | 2022-06-28 | 西南石油大学 | Shale gas reservoir fracturing horizontal well fracturing transformation parameter recommendation method |
| CN114676631B (en) * | 2022-03-25 | 2024-04-16 | 西南石油大学 | Shale gas reservoir fracturing horizontal well fracturing transformation parameter recommendation method |
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