CN111188613A - Method and system for determining well control radius of tight gas reservoir gas well - Google Patents
Method and system for determining well control radius of tight gas reservoir gas well Download PDFInfo
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/08—Measuring diameters or related dimensions at the borehole
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- G—PHYSICS
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- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
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Abstract
The invention provides a method and a system for determining a well control radius of a tight gas reservoir gas well, which fully consider the characteristic of heterogeneity of a tight gas reservoir and calculate the well control radius of the tight gas reservoir gas well according to a fracturing fracture control radius and a starting pressure control radius. The tight gas reservoir gas well calculated by the method has accurate well control radius and reasonable well spacing arrangement, can accurately reflect the actual development of a tight gas reservoir heterogeneous reservoir and improves the recovery ratio of the gas well.
Description
Technical Field
The invention belongs to the technical field of oil and gas field development engineering in the petroleum industry, and particularly relates to a method and a system for determining a well control radius of a gas well of a compact gas reservoir.
Background
With the continuous development of the oil and gas industry, the conventional oil and gas resources and reserves are reduced day by day, and the development center of gravity of the oil and gas industry is gradually shifted to the unconventional oil and gas resources mainly comprising dense oil/gas, shale oil/gas and the like. In particular for dense gas reservoirs, exploration and development of dense gas reservoirs have been rapidly developed in recent years due to the need for environmental protection and the support of national natural gas development strategies. Particularly, in the development stage of the gas reservoir, the determination of the reasonable development well spacing is the key of the efficient development and utilization of the gas reservoir. The over-large well spacing can cause that the reserves between wells can not be completely used, thus causing resource waste; if the well spacing is too small, well-to-well interference can be caused, and the production dynamics and the ultimate recovery rate of the gas well are influenced.
The accurate knowledge of the well control radius of the gas well is an important basis for making a reasonable well spacing, and the determination of the well control radius of the gas well can provide reference for making a reasonable well spacing range and avoid the phenomenon that the deviation between a development well spacing and an actual well control range is too large to cause unused wells or interference among wells.
However, different from the conventional gas reservoir, the compact gas reservoir has compact reservoir, narrow pore throat, small reservoir deposition scale, large deposition change and strong reservoir heterogeneity. The conventional well control range theoretical calculation method is established based on the conventional gas reservoir homogeneous reservoir, and actually, due to the strong heterogeneity of a compact reservoir, the seepage of fluid in the reservoir is influenced to a great extent, the actual seepage capability of the fluid is far different from that of the homogeneous reservoir, and the actual well control radius of a gas well is also greatly different from that of the homogeneous reservoir. Therefore, the existing method for calculating the well control radius of the homogeneous reservoir cannot accurately reflect the actual development condition of the heterogeneous reservoir of the dense gas reservoir, and is not suitable for calculating the well control radius of the dense gas reservoir any more.
Disclosure of Invention
The invention aims to provide a method and a system for determining a tight gas reservoir gas well control radius, which are used for solving the problem that a homogeneous reservoir gas well control radius calculation method in the prior art is not suitable for calculation of the tight gas reservoir gas well control radius.
In order to achieve the aim, the invention provides a method for determining the well control radius of a tight gas reservoir gas well, which comprises the following steps:
1) sampling rock cores from the same layer in a research target area, and testing the permeability of each rock core to obtain the permeability distribution condition in the research target;
2) selecting rock cores with different permeabilities, carrying out starting pressure test on each rock core, obtaining corresponding starting pressure gradients, and obtaining the relation between the permeabilities and the corresponding starting pressure gradients;
3) calculating the starting pressure gradient of the heterogeneous reservoir in the target area according to the relation between the permeability and the corresponding starting pressure gradient and the permeability distribution condition;
4) calculating the starting pressure control radius of the tight gas reservoir gas well according to the original bottom pressure of the gas reservoir, the pressure of the abandoned gas reservoir stratum and the starting pressure gradient of the heterogeneous reservoir in the target area;
5) and calculating the well control radius of the tight gas reservoir gas well according to the fracture control radius and the starting pressure control radius.
The method fully considers the characteristic of heterogeneity of the compact gas reservoir, and calculates the well control radius of the compact gas reservoir gas well according to the fracture control radius and the starting pressure control radius. The tight gas reservoir gas well calculated by the method has accurate well control radius and reasonable well spacing arrangement, can accurately reflect the actual development of a tight gas reservoir heterogeneous reservoir and improves the recovery ratio of the gas well.
Further, the obtaining process of the permeability distribution in the step 1) is as follows: dividing the obtained permeability of each core according to a fixed permeability interval to obtain each permeability interval, counting the number of cores in each permeability interval, determining the core ratio in each permeability interval, and taking the core ratio as the frequency value of the core.
In order to obtain the relationship between permeability and corresponding start-up pressure gradient, in step 1), the relationship between permeability and corresponding start-up pressure gradient is expressed as:
λ＝C·k-a
wherein, lambda is starting pressure gradient with the unit of MPa/m, k is core permeability with the unit of mD, C is experiment fitting coefficient with the unit of MPa/(m.mD), and α is experiment fitting coefficient without dimension.
In order to obtain the starting pressure gradient of the heterogeneous reservoir in the target area, the calculation formula of the starting pressure gradient of the heterogeneous reservoir in the target area is as follows:
wherein f isiThe frequency value of the ith type core is dimensionless; lambda [ alpha ]iThe starting pressure gradient of the i-th rock core is expressed in MPa/m.
In order to obtain the starting pressure control radius, the calculation formula of the starting pressure control radius of the tight gas reservoir gas well is as follows:
wherein gamma is the starting pressure control radius of the compact gas reservoir gas well, and the unit is m; peThe original formation pressure of the gas reservoir is expressed in MPa; pafIs the pressure of the gas reservoir waste stratum and has the unit of MPa.
In order to obtain the well control radius of the tight gas reservoir gas well, the calculation formula of the well control radius of the tight gas reservoir gas well is as follows:
γ1＝γf+γ
wherein, γ1The well control radius of a tight gas reservoir gas well is m; gamma rayfThe control radius of the fracture is expressed in m.
The invention also provides a tight gas reservoir gas well control radius determination system, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the processor executes the program to realize the following steps:
1) on the basis of carrying out core sampling and permeability testing on the same layer in a research target area, obtaining the permeability distribution condition in the research target through computer program analysis in a processor;
2) calculating starting pressure test results of cores with different permeabilities by a computer program in a processor to obtain corresponding starting pressure gradients and obtain the relationship between the permeabilities and the corresponding starting pressure gradients;
3) calculating the starting pressure gradient of the heterogeneous reservoir in the target area according to the relation between the permeability and the corresponding starting pressure gradient and the permeability distribution condition;
4) calculating the well control radius of the tight gas reservoir gas well according to the original bottom pressure of the gas reservoir, the pressure of the abandoned gas reservoir stratum and the starting pressure gradient of the heterogeneous reservoir in the target area;
5) and calculating the well control radius of the compact gas reservoir fractured gas well according to the fracture control radius and the starting pressure control radius.
The method fully considers the characteristic of heterogeneity of the compact gas reservoir, and calculates the well control radius of the compact gas reservoir gas well according to the fracture control radius and the starting pressure control radius. The tight gas reservoir gas well calculated by the method has accurate well control radius and reasonable well spacing arrangement, can accurately reflect the actual development of a tight gas reservoir heterogeneous reservoir and improves the recovery ratio of the gas well.
Further, the obtaining process of the permeability distribution in the step 1) is as follows: dividing the obtained permeability of each core according to a fixed permeability interval to obtain each permeability interval, counting the number of cores in each permeability interval, determining the core ratio in each permeability interval, and taking the core ratio as the frequency value of the core.
In order to obtain the relationship between permeability and corresponding start-up pressure gradient, in step 1), the relationship between permeability and corresponding start-up pressure gradient is expressed as:
λ＝C·k-a
wherein, lambda is starting pressure gradient with the unit of MPa/m, k is core permeability with the unit of mD, C is experiment fitting coefficient with the unit of MPa/(m.mD), and α is experiment fitting coefficient without dimension.
In order to obtain the starting pressure gradient of the heterogeneous reservoir in the target area, the calculation formula of the starting pressure gradient of the heterogeneous reservoir in the target area is as follows:
wherein f isiThe frequency value of the ith type core is dimensionless; lambda [ alpha ]iThe starting pressure gradient of the i-th rock core is expressed in MPa/m.
Drawings
FIG. 1 is a graph of the frequency of permeability distribution in a target zone according to the present invention;
FIG. 2 is a graph of the onset pressure gradient versus permeability for a target zone in accordance with the present invention;
FIG. 3 is a schematic representation of fractured gas well flow and control radius of the present invention.
Detailed Description
The following further describes embodiments of the present invention with reference to the drawings:
the invention provides a method for determining a well control radius of a tight gas reservoir gas well, which comprises the following steps:
1) sampling rock cores from the same layer in a research target area, and testing the permeability of each rock core to obtain the permeability distribution condition in the research target;
2) selecting rock cores with different permeabilities, carrying out starting pressure test on each rock core, obtaining corresponding starting pressure gradients, and obtaining the relation between the permeabilities and the corresponding starting pressure gradients;
3) calculating the starting pressure gradient of the heterogeneous reservoir in the target area according to the relation between the permeability and the corresponding starting pressure gradient and the permeability distribution condition;
4) calculating the starting pressure control radius of the tight gas reservoir gas well according to the original bottom pressure of the gas reservoir, the pressure of the abandoned gas reservoir stratum and the starting pressure gradient of the heterogeneous reservoir in the target area;
5) and calculating the well control radius of the tight gas reservoir gas well according to the fracture control radius and the starting pressure control radius.
Specifically, the method for calculating the well control radius of the gas well comprises three main steps of researching permeability distribution frequency analysis of a target area, starting pressure gradient test of different permeabilities and determining the well control radius.
The permeability distribution frequency analysis of a research target area is obtained through permeability testing, permeability testing is carried out on all sampling rock cores of the same layer in the research target area to obtain the permeability distribution condition in the research target area, the obtained permeability of each rock core is divided according to fixed permeability intervals to obtain each permeability interval, the number of the rock cores in each permeability interval is counted, the rock core proportion in each permeability interval is determined, the rock core proportion is used as the frequency value of the rock core, and the permeability distribution map of the research target area is drawn.
The permeability starting pressure gradient test of different cores is mainly obtained by a method of indoor core non-Darcy seepage starting pressure test. On the basis of core testing, selecting 5-10 cores with different permeability levels, obtaining starting pressure gradients of different cores through starting pressure testing, obtaining a curve of the relation between the starting pressure gradients of the cores and the permeability, and fitting to obtain a starting pressure gradient change equation along with the permeability as follows:
λ＝C·k-a
wherein, lambda is starting pressure gradient with the unit of MPa/m, k is core permeability with the unit of mD, C is experiment fitting coefficient with the unit of MPa/(m.mD), and α is experiment fitting coefficient without dimension.
Calculating the starting pressure gradient of the heterogeneous reservoir in the target area according to the permeability of the cores with different permeability levels and the starting pressure gradient of the core corresponding to the permeability, wherein the calculation formula is as follows:
wherein f isiThe frequency value of the ith type core is dimensionless; lambda [ alpha ]iThe starting pressure gradient of the i-th rock core is expressed in MPa/m.
Then, calculating the starting pressure control radius of the tight gas reservoir gas well according to the original bottom pressure of the gas reservoir, the abandoned formation pressure of the gas reservoir and the starting pressure gradient of the heterogeneous reservoir in the target area, wherein the expression is as follows:
wherein gamma is the starting pressure control radius of the compact gas reservoir gas well, and the unit is m; peThe original formation pressure of the gas reservoir is expressed in MPa; pafIs the pressure of the gas reservoir waste stratum and has the unit of MPa.
For a tight gas reservoir fracturing gas well, the flow of the fracture is considered to be mainly in a fracturing modification area, and no starting pressure gradient exists, and the calculation formula of the well control radius of the tight gas reservoir gas well is as follows:
γ1＝γf+γ
wherein, γ1The well control radius of a tight gas reservoir gas well is m; gamma rayfThe control radius of the fracture is expressed in m.
Through the calculation process, the characteristics of the heterogeneous reservoir of the compact gas reservoir are fully considered, the well control radius result of the gas well of the compact gas reservoir is accurate, and the actual situation of the heterogeneous reservoir of the compact gas reservoir can be reflected better.
The method of the invention is verified below with a specific example:
in this embodiment, a well region of an eastern-wining dense gas reservoir in an Ordos basin is taken as an example, 306 cores of a H1-3 layer, which is a main stress layer of the well region, are selected, a permeability test is performed, and core permeability distribution frequency analysis is performed within a range of 0.1mD, and the result is shown in fig. 1.
The result shows that the permeability of the rock core of the target zone 306 is distributed in the interval of 0-5mD, the average permeability is 0.95mD, the permeability distribution is obviously uneven, and the obvious J-shaped distribution characteristic is presented. The rock cores with the permeability of 0-1mD occupy 66.3% of the total number of rock cores, and the proportion of the rock cores in different permeability intervals, namely the frequency value of each type of rock core can be seen from figure 1.
Selecting 8 cores with different permeability levels from the 306 cores of the target zone to perform a starting pressure gradient test, drawing the result into a starting pressure gradient-permeability relation curve, and performing curve fitting, wherein the result is shown in the attached figure 2. The equation of change of the starting pressure gradient of the target area along with the permeability is obtained by fitting as follows:
λ＝0.1091·k-0.433
the specific calculation method of the average starting pressure gradient of the reservoir comprises the following steps: the permeability distribution frequencies in fig. 1 are multiplied by the corresponding starting pressure gradients in fig. 2, respectively, and finally combined and added. Specifically, in fig. 1, the average permeability of the core is 0.05mD in the distribution range with a permeability of 0-0.1mD of 15.21%, and by analogy, the average starting pressure gradient after heterogeneous correction in the target zone is obtained as follows:
substituting each value into the above formula yields:
λ＝0.1091·(0.1521·0.05-0.043+0.1521·0.15-0.043+…+0.0195·4.95-0.043)
＝0.072MPa/m
the original formation pressure of the gas reservoir of the target area is 27.2MPa, the pressure of the abandoned formation is 5MPa, and then the starting pressure well control radius of the gas well of the target area is calculated according to the specific numerical values of the original bottom pressure and the abandoned bottom pressure of the gas reservoir of the target area, and the calculation formula can be expressed as follows:
in the embodiment, the gas wells in the target area are all put into production by fracturing, and the fracturing radius gammafIs 100 m. In this case, since it is considered that the fracture flow is mainly in the fracture modification area and there is no starting pressure gradient, the actual control range of the gas well can be represented by fig. 3, and the calculation result of the well control radius of the gas well of the target well area is as follows:
γ1＝γf+γ＝(308+100)m＝408m
therefore, the well control radius of the fractured gas well of the target area is finally obtained to be 408 m.
According to the actual well testing interpretation result of the gas well in the target area, the well control radius obtained by gas well interpretation is 425m, the error between the well control radius of the gas well obtained by the method and the actual well testing interpretation result is only 4%, the result has higher accuracy, and the requirement of field engineering calculation is completely met.
The invention also provides a system for determining the well control radius of the tight gas reservoir gas well, which is a process or program corresponding to the method.
The specific embodiments are given above, but the present invention is not limited to the above-described embodiments. The basic idea of the present invention lies in the above basic scheme, and it is obvious to those skilled in the art that no creative effort is needed to design various modified models, formulas and parameters according to the teaching of the present invention. Variations, modifications, substitutions and alterations may be made to the embodiments without departing from the principles and spirit of the invention, and still fall within the scope of the invention.
Claims (10)
1. A method for determining a well control radius of a tight gas reservoir gas well is characterized by comprising the following steps:
1) sampling rock cores from the same layer in a research target area, and testing the permeability of each rock core to obtain the permeability distribution condition in the research target;
2) selecting rock cores with different permeabilities, carrying out starting pressure test on each rock core, obtaining corresponding starting pressure gradients, and obtaining the relation between the permeabilities and the corresponding starting pressure gradients;
3) calculating the starting pressure gradient of the heterogeneous reservoir in the target area according to the relation between the permeability and the corresponding starting pressure gradient and the permeability distribution condition;
4) calculating the starting pressure control radius of the tight gas reservoir gas well according to the original bottom pressure of the gas reservoir, the pressure of the abandoned gas reservoir stratum and the starting pressure gradient of the heterogeneous reservoir in the target area;
5) and calculating the well control radius of the tight gas reservoir gas well according to the fracture control radius and the starting pressure control radius.
2. The tight gas reservoir well control radius determination method as recited in claim 1, wherein the obtaining of the permeability distribution in step 1) comprises: dividing the obtained permeability of each core according to a fixed permeability interval to obtain each permeability interval, counting the number of cores in each permeability interval, determining the core ratio in each permeability interval, and taking the core ratio as the frequency value of the core.
3. Method for determining the well control radius of a tight gas reservoir well according to claim 1 or 2, characterized in that in step 2) the relation between the permeability and the corresponding start-up pressure gradient is expressed as:
λ＝C·k-a
wherein, lambda is starting pressure gradient with the unit of MPa/m, k is core permeability with the unit of mD, C is experiment fitting coefficient with the unit of MPa/(m.mD), and α is experiment fitting coefficient without dimension.
4. The tight gas reservoir gas well control radius determination method as recited in claim 3, wherein the starting pressure gradient of the heterogeneous reservoir in the target zone is calculated by the formula:
wherein f isiThe frequency value of the ith type core is dimensionless; lambda [ alpha ]iThe starting pressure gradient of the i-th rock core is expressed in MPa/m.
5. The tight gas reservoir gas well control radius determination method as recited in claim 4, wherein the starting pressure control radius of the tight gas reservoir gas well is calculated by the formula:
wherein gamma is the starting pressure control radius of the compact gas reservoir gas well, and the unit is m; peThe original formation pressure of the gas reservoir is expressed in MPa; pafIs the pressure of the gas reservoir waste stratum and has the unit of MPa.
6. The tight gas reservoir gas well control radius determination method as recited in claim 5, wherein the tight gas reservoir gas well control radius is calculated by the formula:
γ1＝γf+γ
wherein, γ1The well control radius of a tight gas reservoir gas well is m; gamma rayfThe control radius of the fracture is expressed in m.
7. A tight gas reservoir gas well control radius determination system comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, wherein the processor when executing the program performs the steps of:
1) on the basis of carrying out core sampling and permeability testing on the same layer in a research target area, obtaining the permeability distribution condition in the research target through computer program analysis in a processor;
2) calculating starting pressure test results of cores with different permeabilities by a computer program in a processor to obtain corresponding starting pressure gradients and obtain the relationship between the permeabilities and the corresponding starting pressure gradients;
3) calculating the starting pressure gradient of the heterogeneous reservoir in the target area according to the relation between the permeability and the corresponding starting pressure gradient and the permeability distribution condition;
4) calculating the starting pressure control radius of the tight gas reservoir gas well according to the original bottom pressure of the gas reservoir, the pressure of the abandoned gas reservoir stratum and the starting pressure gradient of the heterogeneous reservoir in the target area;
5) and calculating the well control radius of the compact gas reservoir fractured gas well according to the fracture control radius and the starting pressure control radius.
8. The tight gas reservoir well control radius determination system as recited in claim 7, wherein the obtaining of the permeability profile in step 1) is: dividing the obtained permeability of each core according to a fixed permeability interval to obtain each permeability interval, counting the number of cores in each permeability interval, determining the core ratio in each permeability interval, and taking the core ratio as the frequency value of the core.
9. Tight gas reservoir well control radius determination system according to claim 7 or 8, characterized in that in step 2) the relation between permeability and corresponding start-up pressure gradient is expressed as:
λ＝C·k-a
wherein, lambda is starting pressure gradient with the unit of MPa/m, k is core permeability with the unit of mD, C is experiment fitting coefficient with the unit of MPa/(m.mD), and α is experiment fitting coefficient without dimension.
10. The tight gas reservoir well control radius determination system as recited in claim 9, wherein the starting pressure gradient of the heterogeneous reservoir within the target zone is calculated by the formula:
wherein f isiThe frequency value of the ith type core is dimensionless; lambda [ alpha ]iThe starting pressure gradient of the i-th rock core is expressed in MPa/m.
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| CN114547850A (en) * | 2022-01-10 | 2022-05-27 | 西南石油大学 | Gas well early recovery ratio calculation method based on multiple regression |
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN114547850A (en) * | 2022-01-10 | 2022-05-27 | 西南石油大学 | Gas well early recovery ratio calculation method based on multiple regression |
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