CN113803029A - Method and device for adjusting coal bed gas well pattern and computer readable storage medium - Google Patents

Method and device for adjusting coal bed gas well pattern and computer readable storage medium Download PDF

Info

Publication number
CN113803029A
CN113803029A CN202010544210.2A CN202010544210A CN113803029A CN 113803029 A CN113803029 A CN 113803029A CN 202010544210 A CN202010544210 A CN 202010544210A CN 113803029 A CN113803029 A CN 113803029A
Authority
CN
China
Prior art keywords
well
area
range
determining
produced
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
CN202010544210.2A
Other languages
Chinese (zh)
Other versions
CN113803029B (en
Inventor
张建国
张聪
崔新瑞
乔茂坡
张武昌
刘春春
张金笑
彭鹤
周立春
马辉
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Petrochina Co Ltd
Original Assignee
Petrochina Co Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Petrochina Co Ltd filed Critical Petrochina Co Ltd
Priority to CN202010544210.2A priority Critical patent/CN113803029B/en
Publication of CN113803029A publication Critical patent/CN113803029A/en
Application granted granted Critical
Publication of CN113803029B publication Critical patent/CN113803029B/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/006—Production of coal-bed methane
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F30/00—Computer-aided design [CAD]
    • G06F30/20—Design optimisation, verification or simulation

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Theoretical Computer Science (AREA)
  • Computer Hardware Design (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • Evolutionary Computation (AREA)
  • Geometry (AREA)
  • General Engineering & Computer Science (AREA)
  • General Physics & Mathematics (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Feedback Control In General (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

The disclosure provides a method and a device for adjusting a coal bed methane well pattern and a computer readable storage medium, and belongs to the field of coal bed methane development. The method comprises the following steps: determining a well control range of a produced old well in a target coal-bed gas well network, wherein the well control range refers to the maximum boundary of reservoir resources which can be produced by a coal-bed gas well; and determining a scheme of a new well deployed in the range of the unused resources in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network, wherein the range of the unused resources is the range except the well control range of the produced old well in the defined range of the target coal-bed gas well network, and the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range.

Description

Method and device for adjusting coal bed gas well pattern and computer readable storage medium
Technical Field
The disclosure relates to the field of coal bed methane development, and in particular to a method and a device for adjusting a coal bed methane well pattern and a computer readable storage medium.
Background
The coal bed gas reservoir has the characteristic of self generation and self storage, and the coal bed gas is mainly generated on the surface of a coal matrix in an adsorption state and is desorbed and produced after drainage and pressure reduction. In the development process of the coal bed gas of the fan village block in the Qin basin, researchers gradually recognize that a coal reservoir is a hypotonic reservoir, the permeability is generally lower than 1mD, and the local well area is even lower than 0.1mD, so that the pressure drop of a single well is slowly expanded, and a large-range pressure drop area can be formed only by long-term drainage and mining; meanwhile, the coal reservoir has the characteristic of a reservoir with strong non-mean value, particularly in the direction with poor permeability, the pressure of the reservoir drops more slowly in the drainage process, the pressure drop range of a single well is often in an irregular shape, so that an area with unswept pressure drop exists in a well pattern, and the coal bed gas resources in the area cannot be effectively used. Furthermore, due to topographical conditions, some of the design well locations are forced to cancel, resulting in a localized well pattern that is imperfect and a large area of non-use exists. Therefore, it is necessary to adjust the well pattern to fully utilize the remaining resources in the well pattern and to fully improve the block development performance.
At present, three well pattern adjusting modes implemented in the fan village block comprise that firstly, on the original irregular basic well pattern, a reasonable, perfect and regular well pattern is formed by drilling an adjusting well; secondly, drilling an encrypted well on an original perfect basic well network, shortening the well spacing and promoting the formation of area depressurization; and thirdly, aiming at the uncontrolled area of the original well pattern, namely a blank area, drilling an adjusting well, and using a new reserve.
The well pattern adjusting mode is mainly used for deploying new wells by reducing the well spacing, is suitable for adjusting a large blank range, and easily influences the normal production of adjacent wells in a small range, such as the adjacent old wells are penetrated in the fracturing process, and the yield of the adjacent wells is greatly reduced.
Disclosure of Invention
The embodiment of the disclosure provides a method and a device for adjusting a coal bed methane well pattern and a computer readable storage medium, which can avoid the situation that the yield of an adjacent well is greatly reduced due to the fact that the adjacent old well is penetrated in a fracturing process of a new well. The technical scheme is as follows:
in a first aspect, a method for adjusting a coal bed methane well pattern is provided, the method comprising:
determining a well control range of a produced old well in a target coal-bed gas well network, wherein the well control range refers to the maximum boundary of reservoir resources which can be produced by a coal-bed gas well;
and determining a scheme of a new well deployed in the range of the unused resources in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network, wherein the range of the unused resources is the range except the well control range of the produced old well in the defined range of the target coal-bed gas well network, and the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range.
Optionally, the determining a well control range of an old well put into production in the coal-bed gas well network includes:
determining a pressure drop expansion form of the produced old well, wherein the pressure drop expansion form refers to a shape of a boundary reached by gradual outward expansion by gradually reducing the pressure by taking a single well as a center along with the production and drainage;
determining the area of a desorption range of the produced old well, wherein the desorption range refers to the boundary of a coal reservoir capable of desorbing produced gas;
and determining the desorption range of the produced old well based on the pressure drop expansion form and the desorption range area of the produced old well, and taking the desorption range of the produced old well as the well control range of the produced old well.
Optionally, the determining an area of a desorption range of the commissioned old well comprises:
determining the gas content of the produced old well;
determining the accumulated gas production rate of the produced old well;
and dividing the accumulated gas production rate of the produced old well by the gas content of the produced old well to obtain the area of the desorption range of the produced old well.
Optionally, the determining the gas production capacity of the old well put into production comprises:
when the yield of the produced old well is in a decreasing period, determining the accumulated gas production rate of the produced old well as the current accumulated gas production rate of the produced old well; alternatively, the first and second electrodes may be,
and when the yield of the produced old well is not in the decline period, determining the predicted accumulative gas production of the produced old well within the target age, and taking the predicted accumulative gas production of the produced old well within the target age as the accumulative gas production of the produced old well.
Optionally, the unmoved resource comprises a plurality of discretely distributed zones, the pattern of new wells deployed within the volume of the unmoved resource comprises a type of new wells deployed for each zone in the unmoved resource,
the scheme for determining new wells deployed within the scope of the unmoved resources comprises at least one of:
determining that a new well type deployed in a first area is a horizontal well, wherein the first area is an area with an area larger than or equal to a first area;
determining that the type of a deployed new well in a second area is a horizontal well, wherein the second area is an area with an area smaller than a first area and larger than or equal to a second area, and the distance between a well control range of a well hole and an adjacent old well does not exceed a first distance, and the first area is larger than the second area;
determining that a new well type deployed in a third region is a horizontal well, wherein the third region is a region with an area smaller than a second area and larger than or equal to the third area and is located in a horizontal well cascading region, the horizontal well cascading region comprises a plurality of third regions, each third region in the horizontal well cascading region is arranged at intervals, the interval distance between every two adjacent third regions does not exceed a second distance, the sum of the areas of all the third regions in the horizontal well cascading region is equal to or larger than the second area, and the third area is smaller than the second area;
and determining that the type of the new well deployed in a fourth area is a vertical well, wherein the fourth area is an area which is smaller than the second area, larger than or equal to the third area and is not located in the area where the horizontal wells can be connected in series.
Optionally, the plan of new wells deployed within the scope of the unmoved resource further includes well locations of the deployed new wells for the respective zones in the unmoved resource, the well locations including a well site and a wellbore trajectory;
the scheme for determining new wells deployed within the scope of the unmoved resources further comprises:
determining the well control range of the deployed new well in the region;
and determining the well site and the well track of the new well based on the determined well control range of the deployed new well in the region.
Optionally, the method further comprises:
determining a profitability of each zone in the unmoved resource based on the type and well location of the deployed new wells for each zone in the unmoved resource, respectively;
when the profitability of the area is less than the target profitability, adjusting the type and well placement of deployed new wells of the area to make the profitability of the area greater than or equal to the target profitability.
Optionally, before the determining, based on the determined well control range of the produced old well in the target coal-bed gas well network, a scheme of a new well deployed in the range of the unutilized resource in the target coal-bed gas well network, the method further includes:
determining the resource amount and the gas production amount of each area in the unused resources;
determining the adjustment priority of each region based on the resource amount and the gas production rate of each region in the unused resources, wherein the higher the resource amount and the gas production rate of each region are, the higher the adjustment priority of each region is;
the scheme for determining the new well deployed in the range of the unutilized resources in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network comprises the following steps:
selecting a target number of regions from the unused resources according to the sequence of the adjustment priorities of the regions from high to low;
a plan for new wells deployed within the selected target number of zones is determined.
In a second aspect, there is provided an adjustment device for a coal bed methane well pattern, the adjustment device comprising:
the system comprises a first determining module, a second determining module and a control module, wherein the first determining module is used for determining a well control range of a produced old well in a target coal-bed gas well network, and the well control range refers to the maximum boundary of reservoir resources which can be produced by a coal-bed gas well;
and the second determination module is used for determining a scheme of a new well deployed in the range of the resources which are not used in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network, wherein the range of the resources which are not used is the range, except the well control range of the produced old well, in the defined range of the target coal-bed gas well network, and the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range.
In a third aspect, a device for adjusting a coal bed methane well pattern is provided, which includes a memory and a processor, wherein the memory stores a computer program operable on the processor, and the processor is configured to implement the aforementioned method for adjusting a coal bed methane well pattern when executing the computer program.
In a fourth aspect, a computer-readable storage medium is provided, and at least one instruction is stored in the computer-readable storage medium, and the instruction is loaded and executed by a processor to implement the aforementioned adjustment method for the coalbed methane well pattern.
The technical scheme provided by the embodiment of the disclosure has the following beneficial effects:
determining a well control range of an operated old well in a target coal-bed gas well network, then removing the well control range of the operated old well from a defined range of the target coal-bed gas well network to obtain a range of resources which are not used in the target coal-bed gas well network, and then determining a scheme of a new well deployed in the range of the resources which are not used based on the size of the range of the resources which are not used; the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range, the boundary of the deployed new well can not interfere with the well control range of the produced old well or the interference area is small, the adjacent old well can be prevented from being pressed through in the fracturing process of the new well, so that the yield of the adjacent well is greatly reduced, and the adjustment target of the coal bed gas well pattern is realized.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present disclosure, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present disclosure, and it is obvious for those skilled in the art to obtain other drawings based on the drawings without creative efforts.
FIG. 1 is a flow chart of a method of adjusting a coalbed methane well pattern provided by an embodiment of the present disclosure;
FIG. 2 is a flow chart of a method of adjusting a coalbed methane well pattern provided by an embodiment of the present disclosure;
FIG. 3 is a schematic illustration of an exemplary pressure drop expansion profile provided by an embodiment of the present disclosure;
FIG. 4 is a schematic illustration of the scope of unused resources provided by embodiments of the present disclosure;
FIG. 5 is a schematic illustration of a horizontal well deployment provided by embodiments of the present disclosure;
FIG. 6 is a schematic illustration of a vertical well deployment provided by an embodiment of the present disclosure;
FIG. 7 is a block diagram illustrating an adjustment apparatus for a coalbed methane well pattern according to an embodiment of the present disclosure;
FIG. 8 is a block diagram illustrating an apparatus for adjusting a coalbed methane well pattern according to an embodiment of the present disclosure;
fig. 9 is a block diagram of an adjustment apparatus for a coal bed methane well pattern according to an embodiment of the present disclosure.
Detailed Description
To make the objects, technical solutions and advantages of the present disclosure more apparent, embodiments of the present disclosure will be described in detail with reference to the accompanying drawings.
The terms related to the present embodiment are explained as follows.
The well pattern refers to the distribution mode of oil, gas and water injection wells in the development process of oil and gas fields.
The coal bed gas well pattern is the shape of the coal bed gas well group arranged on the ground.
And the well control range refers to the maximum boundary of reservoir resources which can be produced by the coal-bed gas well.
The pressure drop expansion form refers to the shape of the boundary reached by gradually reducing the pressure by taking a single well as the center and gradually expanding outwards as the drainage and production are carried out. Due to the restriction of the direction and density of the fractures around a single well, the pressure of different wells may spread outward in different shapes, which may be circular, elliptical or even irregular.
And the desorption range refers to the boundary of the coal reservoir capable of desorbing the produced gas. The coal bed gas can be normally analyzed and output within the range lower than the analysis pressure, and the analysis range is smaller than the pressure drop expansion range.
A microstructure, which refers to a structure with a small size (<1000m) on the plane of a coal reservoir and small fluctuation (<10m) in the longitudinal direction; including local small protrusions, small nose-like structures, small broken nose structures, small depressions, small grooves, small broken furrows and the like.
Well location refers to the geographic location of an oil well, gas well, etc.
The wellsite refers to a drilling site, and if the wellsite is arranged, the wellsite is arranged on the plane of the whole drilling site.
A wellbore trajectory refers to the path a well takes to reach a target area in the subsurface from a surface wellhead location.
Fig. 1 is a flowchart of a method for adjusting a coal bed methane well pattern according to an embodiment of the present disclosure. Referring to fig. 1, the process flow includes the following steps.
Step 101, determining a well control range of a produced old well in a target coal-bed gas well network.
In the target coal bed gas well network, the number of the produced old wells is multiple (two or more).
And 102, determining a scheme of a new well deployed in the range of the un-used resources in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network.
The range of the unused resource is the range except the well control range of the produced old well in the demarcated range of the target coal bed methane well pattern.
The overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range.
In the embodiment of the disclosure, the range of the unused resource in the target coal-bed gas well network is obtained by determining the well control range of the produced old well in the target coal-bed gas well network, and then removing the well control range of the produced old well from the defined range of the target coal-bed gas well network, and then the scheme of the new well deployed in the range of the unused resource is determined based on the size of the range of the unused resource; the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range, the boundary of the deployed new well can not interfere with the well control range of the produced old well or the interference area is small, the adjacent old well can be prevented from being pressed through in the fracturing process of the new well, so that the yield of the adjacent well is greatly reduced, and the adjustment target of the coal bed gas well pattern is realized.
Fig. 2 is a flowchart of a method for adjusting a coalbed methane well pattern according to an embodiment of the present disclosure. Referring to fig. 2, the process flow includes the following steps.
Step 201, determining a well control range of a produced old well in a target coal-bed gas well network.
In the target coal bed gas well network, the number of the produced old wells is multiple (two or more).
The well control range of the produced old well in the target coal-bed gas well network can be evaluated in a numerical simulation mode.
Optionally, step 201 comprises the following steps.
Step A, determining the pressure drop expansion form of the produced old well.
And step A, predicting the pressure drop expansion form of the produced old well based on the local microstructure of the produced old well. Optionally, step a comprises the following steps.
And A1, acquiring the local microstructure of the produced old well.
The local microstructure of the commissioned old well may be obtained from a rock sample of the commissioned old well.
And A2, acquiring the corresponding relation between the local microstructure and the crack propagation form.
Because the coal reservoir is a pore fractured reservoir, the heterogeneity of fracture directions determines the difference of pressure drop expansion and the direction of resource utilization, and the fracture expansion form can be used for evaluating the pressure drop expansion form. Fracturing is a main means for increasing the yield of a coal-bed gas well, and aims to enlarge natural fractures of a reservoir on the basis of the natural fractures. In this example, the pressure drop propagation profile was evaluated by fracturing the fracture propagation profile. However, due to the large investment, a small number of wells are generally selected to perform fracture monitoring in the actual production process. The fracture monitoring means that the artificial fracture form in a coal bed in the hydraulic fracturing or production process is visually described by using a technical means. Researchers have found that local microstructure affects the extent of natural fracture development in coal seams. During fracturing, the fracture fractures tend to propagate along the natural fractures. The natural fracture development area has far extension of the fracturing fracture, the natural fracture non-development area has short extension of the fracturing fracture. Therefore, the local microstructure enables evaluation of fracture propagation morphology.
The corresponding relation between the local microstructure and the crack expansion form is obtained by analyzing a large amount of fractured crack monitoring data of the coal-bed gas well and corresponding local microstructure data, and the corresponding relation is stored in a computer.
And A3, acquiring a fracture expansion form corresponding to the local microstructure of the produced old well according to the corresponding relation between the local microstructure and the fracture expansion form, and taking the fracture expansion form corresponding to the local microstructure of the produced old well as a pressure drop expansion form.
FIG. 3 is a schematic illustration of an exemplary pressure drop expansion profile provided by an embodiment of the present disclosure. Referring to fig. 3, taking the drawdown expansion pattern of the vertical well as an example, the black dots in fig. 3 are the cross section of the wellbore, the drawdown expansion pattern of the first vertical well is circular, the drawdown expansion pattern of the second vertical well is elliptical, and the drawdown expansion pattern of the third vertical well is irregular.
And step B, determining the area of the desorption range of the produced old well.
Optionally, step B comprises the following steps.
And step B1, determining the gas content of the produced old well.
The gas content refers to the volume total amount of methane contained in a single well under the unit mass of coal and rock.
The gas content of a single well is generally obtained in a laboratory through coal rock analysis and test.
And step B2, determining the accumulated gas production rate of the produced old well.
Optionally, step B2 includes: it is determined whether the production of the commissioned old well is in a decline period.
And when the yield of the produced old well is in the decreasing period, determining the accumulative gas production rate of the produced old well as the current accumulative gas production rate of the produced old well.
And when the yield of the old well put into production is not in the decline period, determining the predicted accumulated gas production rate of the old well put into production within the target year, and taking the predicted accumulated gas production rate of the old well put into production within the target year as the accumulated gas production rate of the old well put into production.
And determining whether the yield of the produced old well is in a decreasing period according to the change of the yield of the produced old well along with time. If the yield of the produced old well gradually decreases along with the time, determining that the yield of the produced old well is in a decreasing period; conversely, if the production of the commissioned old well is gradually increasing or not changing over time, it is determined that the production of the commissioned old well is not in a decline period.
And determining the predicted accumulative gas production of the produced old well within the target year, comprising the following steps.
Firstly, determining the production degree R of the produced old well within the target age according to the equation (1).
R＝B1+B2+…+Bj，Bx＝A*Bx-1*K (1)
B is the gas production speed of the old well, j is the target age limit, x takes values of 1-j, K is the permeability of the reservoir, and A is the set gas production speed variation coefficient.
Illustratively, the target age is 15 years, i.e., j 15.
And secondly, determining the predicted accumulated gas production rate Q of the produced old well within the target age according to the formula (2) according to the production degree R of the produced old well within the target age.
Q＝R*D (2)
D is geological reserve. The geological reserve refers to the total amount of all coal bed gas resources in a single well control range, the geological reserve D is the resource abundance coefficient of a block multiplied by 0.07, and the resource abundance coefficient of the block is a fixed value.
And step B3, dividing the gas production amount of the produced old well by the gas content of the produced old well to obtain the area of the desorption range of the produced old well.
And finally, obtaining the area S of the well control range as Q/V according to the quotient of the accumulated gas production Q and the gas content V.
And step C, determining the desorption range of the produced old well based on the pressure drop expansion range and the desorption range area of the produced old well, and taking the desorption range of the produced old well as the well control range of the produced old well.
Optionally, firstly, according to the area of the desorption range, obtaining a circular desorption range; secondly, the boundary of the circular desorption range is corrected through the pressure drop expansion form, so that the prediction of the desorption range (well control range) is more consistent with the actual production condition.
Step 202, determining the range of the un-used resources in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network.
The range of the unused resource is the range except the well control range of the produced old well in the demarcated range of the target coal bed methane well pattern.
The unused resources include a number of distributed regions. FIG. 4 is a schematic illustration of the scope of unused resources provided by embodiments of the present disclosure. Referring to FIG. 4, on the current well map, the well control range of the old well is marked (shown in dashed box). Outside the boundaries of the control zone of the old well, i.e., the zones that are not using resources (shown in the blank area). As can be seen from fig. 4, the unused resources are generally in an irregular connection state, and each part (blank) of the unused resources is connected, in this embodiment, the maximum boundary point connecting line of one circle of old wells enclosing a blank region is used as a partition boundary, so as to virtually divide the unused resources into a plurality of regions distributed in a scattered manner, and fig. 4 shows an exemplary region filled with squares, which is in a long strip shape.
Step 203, determining the adjustment priority of each region in the unused resource.
Optionally, step 203 comprises the following steps.
Step a, determining the resource quantity and the gas production quantity of each area in the unused resources.
And calculating the resource amount of each region according to the area, the average gas content, the coal thickness and the coal density of the region.
Take a certain area as an example, its area is 2km2The average gas content of the coal bed is 20m3(t) 5m coal thickness and 1.43X 10 coal density3kg/m3The resource amount of the region is: area 2km2X thickness of coal 5m x coal density (1.43X 10)3kg/m3) X gas content 20m3/t＝286×106m3。
And evaluating the gas production rate of the area according to the development effect of the adjacent old well.
For example: and according to the average stable gas production rate of the adjacent wells being 1000, the gas production capacity of the new well in the area is 1000 according to the calibration.
And b, determining the adjustment priority of each region based on the resource quantity and the gas production of each region in the unused resources, wherein the adjustment priority of each region is higher when the resource quantity and the gas production of each region are larger.
And sequencing the areas according to the resource quantity and the gas production quantity of each area in the unused resources from good to bad. The purpose of the sorting is to determine the next development order according to the adjustment priority of the areas. Good areas are developed first and bad areas are developed later.
And step 204, selecting the regions with the target quantity from the unused resources according to the sequence of the adjustment priorities of the regions from high to low.
The target number may be set according to the development capability, for example, half of the regions may be selected from all the regions for development according to the current development capability and the adjustment priority.
Step 205, determine the plan for new wells deployed within the selected target number of zones.
The plan for new wells deployed within the scope of the unpopulated resource (within the selected target number of zones) includes the types of new wells deployed for each zone in the unpopulated resource.
Optionally, step 205 includes at least one of the following ways.
A scheme for determining new wells deployed within a scope of an unmoved resource, comprising at least one of:
in the first mode, the type of a new well deployed in a first area is determined to be a horizontal well, and the first area is an area with the area larger than or equal to the first area.
And in the second mode, determining that the type of the new well deployed in the second area is a horizontal well, wherein the second area is an area with the area smaller than the first area and larger than or equal to the second area, and the distance between the well control range of the well hole and the adjacent old well is not more than the first distance, and the first area is larger than the second area.
And in a third mode, determining that the type of the new well deployed in the third area is a horizontal well, wherein the third area is an area which is smaller than the second area, larger than or equal to the third area and is located in a horizontal well tandem area, the horizontal well tandem area comprises a plurality of third areas, each third area in the horizontal well tandem area is arranged at intervals, the interval distance between every two adjacent third areas does not exceed the second distance, the sum of the areas of all the third areas in the horizontal well tandem area is equal to or larger than the second area, and the third area is smaller than the second area.
And in a fourth mode, determining that the type of the new well deployed in the fourth area is a vertical well, wherein the fourth area is an area which is smaller than the second area, larger than or equal to the third area and is not located in the area where the horizontal wells can be connected in series.
In step 205, the area of the region may be measured directly on the geological map with an area measurement tool and stored in a computer.
Illustratively, the first area is 0.2km2The second area is 0.1km2And the third area is 0.05km2The first distance and the second distance are 100m, respectively.
It should be noted that, the four determination methods are performed for a single well, and when the area of the area can cover more than two single wells, a deployed single well is determined according to the four determination methods, and then a deployed single well is determined on the remaining area according to the four determination methods until all areas of the area are covered.
Optionally, in the first manner, if the permeability of the first area is greater than the target permeability and the distance between the well control boundary of the well bore and the adjacent old well does not exceed a first distance, the horizontal well deployed in the first area is a screen horizontal well; and if the permeability of the first area is less than or equal to the target permeability, or the permeability of the first area is greater than the target permeability and the distance between the well control range of the well hole and the adjacent old well exceeds the first distance, the horizontal well deployed in the first area is a casing horizontal well.
Illustratively, the target permeability is 0.5 mD.
Optionally, in the second and third manners, the deployed horizontal well is a screen horizontal well.
For the area larger than or equal to the second area, the horizontal well is preferably selected because the vertical well is obviously limited by the ground conditions and cannot be popularized in the region with complex landform and landform, and the horizontal well is easy to popularize in the region with complex landform and landform.
For example, after the X-well region is marked with the unused resource region, it is found to be divided into 8 cells (regions). The 1 st cell has an area exceeding 0.2km2And designing a horizontal well for development and adjustment in the unused resource area. If the fracture is located in the area with the permeability of more than 0.5mD, a screen pipe horizontal well is adopted for development, and the distance between a horizontal well borehole and the tail end (well control range) of the old well fracturing main crack is more than 100 meters; if the permeability is less than 0.5mD, the horizontal well is fractured by adopting a sleeve for development; the area of the 2 nd cell is 0.1-0.2km2Preferentially designing a horizontal well in a community, and designing vertical well deployment when the horizontal well is found to easily influence an old well (the well control range distance between a well bore of the horizontal well and the old well is within 100 meters); the areas of 3 rd, 4 th, 5 th and other 3 th cells are all less than 0.1km2And are not connected with each other, are distributed sporadically, design the vertical well; the areas of 3 cells such as 6 th cell, 7 th cell, 8 th cell and the like are all less than 0.1km2The horizontal wells are intensively distributed in a bead-string shape, and the horizontal wells are sequentially connected in series with 3 cells to complete deployment.
Optionally, the plan for a new well deployed within the scope of the unconsolidated resources (within the selected target number of zones) also includes the well location of the new well, including the well site and the wellbore trajectory.
The well location determination method comprises the following steps.
Firstly, determining the well control range of the deployed new well in the region.
This step may include the following steps.
First, the well control range of the deployed new well is determined.
The well control range of the new well comprises the area and the shape of the well control range.
The determining method of the well control range of the new well is not limited in the embodiment, the well control range of the new well can be set with a uniform well control range according to the type of the new well and stored in a computer in advance, and the well control range of the new well can also be obtained by calculating in a numerical simulation mode according to the geological conditions of the region.
Illustratively, unified well control rangeThe area of the well control range of the casing horizontal well (adopting the casing to support the well hole) is 0.4km2The area of the well control range of the screen pipe horizontal well (adopting the screen pipe to support the well hole) is 0.2km2The shape of the well control range of the horizontal well is a strip shape; the area of the well control range of the vertical well is 0.07km2The shape of the vertical well is an ellipse.
For example, the numerical simulation mode includes that for a horizontal well, calculation can be performed by using a coal bed gas horizontal well staged fracturing fracture extension model proposed by hojee, and the principle is that by using the established fracture length, width and height equations and combining coal reservoir characteristics (including pore structure characteristics, cleat fracture characteristics, methane desorption and adsorption characteristics, diffusion characteristics and seepage characteristics of fluid in the reservoir), the fracturing transformation range of the horizontal well, namely the well control range, can be calculated. Aiming at a vertical well, the research results of predecessors are more, and related contents and methods such as 'Qin-south east block coal reservoir characteristics and coal bed gas development well pattern spacing optimization' proposed by Benping et al or 'coal bed gas development well pattern deployment and optimization method' proposed by Yang Xiuchun et al can be adopted for research, and the principle is that numerical simulation is carried out according to reservoir conditions of domains, natural fracture development characteristics and vertical well fracturing process effects to predict the well control range of the vertical well.
And secondly, determining the well control range of the deployed new well in the area to which the deployed new well belongs according to the shape of the area to which the new well belongs and the determined well control range of the deployed new well.
And according to the principle that the well control ranges of the single wells are uniformly distributed in the corresponding areas, arranging the determined well control ranges of the deployed new wells on the corresponding areas, and thus determining the well control ranges of the new wells in the areas. Thus, the new well and the old well form a regular well pattern as much as possible.
It should be noted that, when the well control range of the new well is arranged, the well control range of the new well can be overlapped with the well control range of the old well, the area pressure reduction can be accelerated to be formed after the overlap, but the overlap area is not suitable to exceed the target overlap range. The target overlap range may be 10% of the well control range of the old well.
Fig. 5 is a schematic diagram of horizontal well deployment provided by the embodiments of the present disclosure. Referring to fig. 5, for horizontal well deployment, corresponding areas (blank areas) are uniformly distributed according to the well control area (diagonal filling) of a single well, so as to determine the well control range of the horizontal well in the areas. Fig. 6 is a schematic diagram of vertical well deployment provided by an embodiment of the present disclosure, and referring to fig. 6, for a vertical well, blank areas are uniformly distributed according to a single well control area (diagonal filling), so as to determine a well control range of the vertical well in an area.
It should be noted that if a plurality of new wells are deployed adjacent to each other, the well control range boundaries between two adjacent wells may overlap each other, but the overlap range should not exceed the target overlap range (e.g., 10%).
Second, based on the determined well control range of the deployed new well in the region, the well site and the well track of the new well are determined.
The wellsite determines the location of the wellhead. The well site of the vertical well is determined in a mode that the well site of the vertical well is positioned at the central position of the well control range of the area where the vertical well belongs; the well site of the horizontal well is positioned at one end of a center connecting line in the length direction of the well control range of the region.
Optionally, if the well site of the adjacent old well is located at one end of a center connecting line in the length direction of the well control range of the region where the horizontal well belongs, the well site of the adjacent old well is adopted as the well site of the horizontal well, and the purpose of saving the well site establishment cost is achieved.
Alternatively, if the topography of the location of the wellsite of the new well is such that it is more difficult to establish the wellsite in a hostile terrain, then an adjacent topography that is more likely to establish the wellsite is selected as the wellsite. Adjacent wellsites create easier terrain, new wellsites can be selected, and old wellsites can be utilized. If the ground of the area E1 is a bad terrain such as a hillside or a valley, drilling can be carried out after the adjacent old well field is expanded; if the ground of the area E2 is a flat terrain, a well site can be newly built to complete drilling construction, and drilling can also be carried out after the adjacent old well site is expanded according to the principle of saving land.
Illustratively, the wellsite location is selected according to different well type drilling requirements when the terrain is not in a bad terrain, such as a flat terrain. Optionally, the horizontal well is selected as an old well site, and the vertical well is selected as a new well site.
The method for determining the borehole trajectory of the horizontal well comprises the step of extending the borehole trajectory of the horizontal well from a wellhead to the length direction of a well control range and enabling the borehole trajectory to be located at the center of the well control range on the premise that the wellhead (well site) is determined.
Optionally, the wellbore trajectory of the horizontal well further meets at least one of the following requirements: the well track is L-shaped; the main branch of the horizontal well borehole track is vertical or oblique to the direction of the maximum main stress in the well control range; the length of the horizontal borehole trajectory does not exceed 1000 m; the track of the well is designed to be inclined upwards; the well control range of the wellbore from the old well is at least greater than a first distance (e.g., 100 m).
The wellbore trajectory of a vertical well is determined in a manner that includes extending the wellbore trajectory of the vertical well vertically downward from the wellhead, provided the wellhead (well site) has been determined.
Optionally, the wellbore trajectory of the vertical well also meets at least one of the following requirements: in the direction of the maximum principal stress, the well distance between a new well and an old well is greater than the maximum water inlet crack length monitored by well fracturing cracks; in the direction of the minimum principal stress, the well spacing between the new well and the old well meets the condition that the well control boundary overlapping area of the new well and the old well in the direction does not exceed the target overlapping range.
And step 206, respectively determining the yield of each area in the unused resource based on the type and the well position of the deployed new well of each area in the unused resource.
When the profitability of the area is less than the target profitability, step 207 is performed. When the profitability of the area is not less than (equal to or greater than) the target profitability, the type and well placement of deployed new wells of the area are kept unchanged.
The profitability of each area in the unused resources can be determined by using a numerical simulation mode provided by the related art (such as the application of the non-equilibrium adsorption model in the coal bed methane numerical simulation proposed by the Guangming and the like). Illustratively, the operation principle of the numerical simulation mode includes:
firstly, a coal bed gas productivity simulation mathematical model is established. The establishment method comprises the steps of firstly, generalizing a geological model according to the characteristics of a coal reservoir (including pore structure characteristics, cleat fracture characteristics, desorption and adsorption characteristics of methane, diffusion characteristics and seepage characteristics of fluid in the reservoir); and deducing a differential equation representing the migration rule of the coal bed gas and the water by using a mathematical method according to the geological model, and establishing a coal bed gas productivity simulation mathematical model by combining definite conditions.
And secondly, predicting gas production and water production of the single well through the coal bed gas productivity simulation mathematical model, and realizing the prediction of the single well development effect.
Then, the obtained prediction of the single well development effect is compared with the actual adjacent well gas production effect and the currently obtained development knowledge for research, and the single well development effect (including the gas production) is more finely and longer-term predicted, so that the change curve of the single well yield along with the development time within the development period is obtained, and the gas production accumulated within the development period is calculated.
Finally, according to the current gas price and the gas production amount accumulated in the development period, the total income in the development period can be obtained, and the total cost generated by single-well development is subtracted, namely the income of the single well; the income of the single well is divided by the total income within the development period, and the income rate of the single well is obtained.
Step 207, the type and well placement of the deployed new wells of the zone are adjusted such that the profitability of the zone is greater than or equal to the target profitability.
The adjusting mode comprises the step of adjusting the number of horizontal wells and vertical wells in the area. After adjusting the type and well placement of the new well, recalculating the rate of return, and when the recalculated rate of return is greater than or equal to the target rate of return, keeping the type and well placement of the deployed new well of the area as the adjusted type and well placement of the deployed new well.
For example, the well control zone F1 has an area of 0.4km2Deployed is a cased horizontal well; the area of the well control range of the adjustment zone F2 was 0.3km21 screen pipe horizontal well and 2 vertical wells are deployed; the area of the well control range of the adjustment zone F3 was 0.2km21-screen horizontal well is deployed; the area of the well control range of the adjustment zone F4 was 0.15km2And 2 vertical wells are deployed.
Respectively carrying out numerical simulation calculation yields on the adjustment areas F1-F4, wherein the target yield is 9%, the yield of F1 is more than 12%, and the implementation is as soon as possible; the yield of F2 is 7%, the calculated yield reaches 11% after the optimized adjustment deployment is 5 vertical wells are developed, and the optimization adjustment deployment is implemented according to the deployment after the adjustment; the yield of F3 is 9%, which can be implemented; the yield of F4 is 4%, the calculated yield reaches 9% after the optimization adjustment is performed to a horizontal well with 1 screen pipe, and the method can be implemented.
In the embodiment of the disclosure, the range of the unused resource in the target coal-bed gas well network is obtained by determining the well control range of the produced old well in the target coal-bed gas well network, and then removing the well control range of the produced old well from the defined range of the target coal-bed gas well network, and then the scheme of the new well deployed in the range of the unused resource is determined based on the size of the range of the unused resource; the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range, the boundary of the deployed new well can not interfere with the well control range of the produced old well or the interference area is small, the adjacent old well can be prevented from being pressed through in the fracturing process of the new well, so that the yield of the adjacent well is greatly reduced, and the adjustment target of the coal bed gas well pattern is realized.
Fig. 7 is a block diagram of an adjustment apparatus for a coal bed methane well pattern according to an embodiment of the present disclosure. Referring to fig. 7, the adjusting apparatus includes: a first determining module 701 and a second determining module 702.
The first determining module 701 is configured to determine a well control range of a produced old well in a target coal-bed gas well network, where the well control range refers to a maximum boundary of reservoir resources that can be produced by a coal-bed gas well.
The second determining module 702 is configured to determine, based on the determined well control range of the produced old well in the target coal-bed gas well network, a scheme of a new well deployed in the range of the un-used resource in the target coal-bed gas well network, where the range of the un-used resource is a range, excluding the well control range of the produced old well, in the defined range of the target coal-bed gas well network, and an overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range.
Optionally, the first determining module 701 is configured to determine a pressure drop expansion form of the produced old well, where the pressure drop expansion form refers to a shape of a boundary reached by gradual outward expansion and gradual reduction of pressure with a single well as the progress of drainage and production; determining the area of a desorption range of the produced old well, wherein the desorption range refers to the boundary of a coal reservoir capable of desorbing gas generated; and determining the desorption range of the produced old well based on the pressure drop expansion form and the desorption range area of the produced old well, and taking the desorption range of the produced old well as the well control range of the produced old well.
Optionally, the first determining module 701 is configured to determine a gas content of the produced old well; determining the accumulated gas production rate of the produced old well; and dividing the gas content of the produced old well by the accumulated gas production of the produced old well to obtain the area of the desorption range of the produced old well.
Optionally, the first determining module 701 is configured to determine, when the yield of the put-in-production old well is in a decreasing period, an accumulated gas production rate of the put-in-production old well as a current accumulated gas production rate of the put-in-production old well; or when the yield of the produced old well is not in the decline period, determining the predicted accumulated gas production rate of the produced old well within the target age limit, and taking the predicted accumulated gas production rate of the produced old well within the target age limit as the accumulated gas production rate of the produced old well.
Optionally, the unmoved resource comprises a plurality of discretely distributed zones, and the pattern of new wells deployed within the area of the unmoved resource comprises a type of new wells deployed for each zone in the unmoved resource.
Accordingly, the second determination module 702, in determining a plan for a new well deployed within the scope of the unmoved resource, includes at least one of: determining that the type of a new well deployed in a first area is a horizontal well, wherein the first area is an area with an area larger than or equal to a first area; determining that the type of a deployed new well in a second area is a horizontal well, wherein the second area is an area with an area smaller than a first area and larger than or equal to a second area, and the distance between a well control range of a well hole and an adjacent old well is not more than a first distance, and the first area is larger than the second area; determining that the type of a new well deployed in a third area is a horizontal well, wherein the third area is an area which is smaller than the second area, larger than or equal to the third area and is located in a horizontal well tandem connection area, the horizontal well tandem connection area comprises a plurality of third areas, each third area in the horizontal well tandem connection area is arranged at intervals, the interval distance between every two adjacent third areas does not exceed a second distance, the sum of the areas of each third area in the horizontal well tandem connection area is equal to or larger than the second area, and the third area is smaller than the second area; and determining that the type of the new well deployed in the fourth area is a vertical well, wherein the fourth area is an area which is smaller than the second area, larger than or equal to the third area and is not located in the area where the horizontal wells can be connected in series.
Optionally, the plan for new wells deployed within the scope of the unmoved resource further includes well locations for the deployed new wells for the respective zones in the unmoved resource, the well locations including the well site and the wellbore trajectory.
Accordingly, the second determining module 702 is configured to determine a well control range of the deployed new well in the area; and determining the well site and the well track of the new well based on the determined well control range of the deployed new well in the region.
Optionally, referring to fig. 8, the adjusting apparatus further includes an adjusting module 703.
The adjusting module 703 is configured to determine, based on the type and well location of the deployed new well in each area of the unused resource, the profitability of each area of the unused resource; when the profitability of the area is less than the target profitability, adjusting the type and well placement of the deployed new wells of the area to make the profitability of the area greater than or equal to the target profitability.
Optionally, the first determining module 701 is further configured to determine the resource amount and the gas production amount of each region in the unused resource; and determining the adjustment priority of each region based on the resource amount and the gas production rate of each region in the unused resources, wherein the adjustment priority of each region is higher when the resource amount and the gas production rate of each region are larger.
Correspondingly, the second determining module 702 is further configured to select a target number of regions from the unused resources in an order from high to low in the adjustment priority of the regions; a plan for new wells deployed within the selected target number of zones is determined.
Fig. 9 is a block diagram of an adjustment apparatus, which may be a computer 300, for a coal bed methane well pattern according to an embodiment of the present disclosure.
The computer 300 includes a Central Processing Unit (CPU)301, a system memory 304 including a Random Access Memory (RAM)302 and a Read Only Memory (ROM)303, and a system bus 305 connecting the system memory 304 and the central processing unit 301. The computer 300 also includes a basic input/output system (I/O system) 306, which facilitates the transfer of information between devices within the computer, and a mass storage device 307, which stores an operating system 313, application programs 314, and other program modules 315.
The basic input/output system 306 comprises a display 308 for displaying information and an input device 309, such as a mouse, keyboard, etc., for a user to input information. Wherein a display 308 and an input device 309 are connected to the central processing unit 301 through an input output controller 310 connected to the system bus 305. The basic input/output system 306 may also include an input/output controller 310 for receiving and processing input from a number of other devices, such as a keyboard, mouse, or electronic stylus. Similarly, an input-output controller 310 may also provide output to a display screen, a printer, or other type of output device.
The mass storage device 307 is connected to the central processing unit 301 through a mass storage controller (not shown) connected to the system bus 305. The mass storage device 307 and its associated computer-readable media provide non-volatile storage for the computer 300. That is, the mass storage device 307 may include a computer-readable medium (not shown) such as a hard disk or CD-ROM drive.
Without loss of generality, computer readable media may comprise computer storage media and communication media. Computer storage 13 media includes volatile and nonvolatile, removable and non-removable media implemented in any method or technology for storage of information such as computer readable instructions, data structures, program modules or other data. Computer storage media includes RAM, ROM, EPROM, EEPROM, flash memory or other solid state memory technology, CD-ROM, DVD, or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices. Of course, those skilled in the art will appreciate that computer storage media is not limited to the foregoing. The system memory 304 and mass storage device 307 described above may be collectively referred to as memory.
According to various embodiments of the invention, the computer 300 may also operate as a remote computer connected to a network through a network, such as the Internet. That is, the computer 300 may be connected to the network 312 through the network interface unit 311, which is connected to the system bus 305, or the network interface unit 311 may be used to connect to other types of networks or remote computer systems (not shown).
The memory further includes one or more programs, and the one or more programs are stored in the memory and configured to be executed by the CPU. The one or more programs include instructions for performing a method of adjusting a coal bed methane well pattern provided by an embodiment of the present invention.
It should be noted that: when the adjustment device for the coal bed methane well pattern provided by the embodiment is used for adjusting the coal bed methane well pattern, the division of the functional modules is only used for illustration, and in practical application, the function distribution can be completed by different functional modules according to needs, that is, the internal structure of the equipment is divided into different functional modules, so as to complete all or part of the functions described above. In addition, the coal bed methane well pattern adjusting device provided by the embodiment and the coal bed methane well pattern adjusting method embodiment belong to the same concept, and specific implementation processes are detailed in the method embodiment and are not described again.
It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by a program instructing relevant hardware, where the program may be stored in a computer-readable storage medium, and the above-mentioned storage medium may be a read-only memory, a magnetic disk or an optical disk, etc.
The above description is intended to be exemplary only and not to limit the present disclosure, and any modification, equivalent replacement, or improvement made without departing from the spirit and scope of the present disclosure is to be considered as the same as the present disclosure.

Claims (11)

1. A method of adjusting a coal bed methane well pattern, the method comprising:
determining a well control range of a produced old well in a target coal-bed gas well network, wherein the well control range refers to the maximum boundary of reservoir resources which can be produced by a coal-bed gas well;
and determining a scheme of a new well deployed in the range of the unused resources in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network, wherein the range of the unused resources is the range except the well control range of the produced old well in the defined range of the target coal-bed gas well network, and the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range.
2. The adjustment method of claim 1, wherein the determining the well control range of the commissioned old well in the coal-bed gas well network comprises:
determining a pressure drop expansion form of the produced old well, wherein the pressure drop expansion form refers to a shape of a boundary reached by gradual outward expansion by gradually reducing the pressure by taking a single well as a center along with the production and drainage;
determining the area of a desorption range of the produced old well, wherein the desorption range refers to the boundary of a coal reservoir capable of desorbing produced gas;
and determining the desorption range of the produced old well based on the pressure drop expansion form and the desorption range area of the produced old well, and taking the desorption range of the produced old well as the well control range of the produced old well.
3. The method of adjusting of claim 2, wherein the determining an area of a desorption range of the commissioned old well comprises:
determining the gas content of the produced old well;
determining the accumulated gas production rate of the produced old well;
and dividing the accumulated gas production rate of the produced old well by the gas content of the produced old well to obtain the area of the desorption range of the produced old well.
4. The adjustment method of claim 3, wherein said determining an accumulated gas production rate of said commissioned old well comprises:
when the yield of the produced old well is in a decreasing period, determining the accumulated gas production rate of the produced old well as the current accumulated gas production rate of the produced old well; alternatively, the first and second electrodes may be,
and when the yield of the produced old well is not in the decline period, determining the predicted accumulative gas production of the produced old well within the target age, and taking the predicted accumulative gas production of the produced old well within the target age as the accumulative gas production of the produced old well.
5. The method of tuning of claim 4, wherein the unmoved resource comprises a plurality of discretely distributed zones, the pattern of new wells deployed within the area of the unmoved resource comprises a type of new wells deployed for each zone in the unmoved resource,
the scheme for determining new wells deployed within the scope of the unmoved resources comprises at least one of:
determining that a new well type deployed in a first area is a horizontal well, wherein the first area is an area with an area larger than or equal to a first area;
determining that the type of a deployed new well in a second area is a horizontal well, wherein the second area is an area with an area smaller than a first area and larger than or equal to a second area, and the distance between a well control range of a well hole and an adjacent old well does not exceed a first distance, and the first area is larger than the second area;
determining that a new well type deployed in a third region is a horizontal well, wherein the third region is a region with an area smaller than a second area and larger than or equal to the third area and is located in a horizontal well cascading region, the horizontal well cascading region comprises a plurality of third regions, each third region in the horizontal well cascading region is arranged at intervals, the interval distance between every two adjacent third regions does not exceed a second distance, the sum of the areas of all the third regions in the horizontal well cascading region is equal to or larger than the second area, and the third area is smaller than the second area;
and determining that the type of the new well deployed in a fourth area is a vertical well, wherein the fourth area is an area which is smaller than the second area, larger than or equal to the third area and is not located in the area where the horizontal wells can be connected in series.
6. The adjustment method of claim 5, wherein the plan of new wells deployed within the scope of the unmoved resource further comprises well locations of the deployed new wells for each zone in the unmoved resource, the well locations comprising a well site and a wellbore trajectory;
the scheme for determining new wells deployed within the scope of the unmoved resources further comprises:
determining the well control range of the deployed new well in the region;
and determining the well site and the well track of the new well based on the determined well control range of the deployed new well in the region.
7. The adjustment method according to claim 6, characterized in that the method further comprises:
determining a profitability of each zone in the unmoved resource based on the type and well location of the deployed new wells for each zone in the unmoved resource, respectively;
when the profitability of the area is less than the target profitability, adjusting the type and well placement of deployed new wells of the area to make the profitability of the area greater than or equal to the target profitability.
8. The adjustment method of claim 5, wherein prior to determining the plan for a new well deployed within the scope of unexploited resources in the target coalbed methane well network based on the determined well control range for the commissioned old well in the target coalbed methane well network, the method further comprises:
determining the resource amount and the gas production amount of each area in the unused resources;
determining the adjustment priority of each region based on the resource amount and the gas production rate of each region in the unused resources, wherein the higher the resource amount and the gas production rate of each region are, the higher the adjustment priority of each region is;
the scheme for determining the new well deployed in the range of the unutilized resources in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network comprises the following steps:
selecting a target number of regions from the unused resources according to the sequence of the adjustment priorities of the regions from high to low;
a plan for new wells deployed within the selected target number of zones is determined.
9. An adjustment device for a coal bed methane well pattern, the adjustment device comprising:
the system comprises a first determining module, a second determining module and a control module, wherein the first determining module is used for determining a well control range of a produced old well in a target coal-bed gas well network, and the well control range refers to the maximum boundary of reservoir resources which can be produced by a coal-bed gas well;
and the second determination module is used for determining a scheme of a new well deployed in the range of the resources which are not used in the target coal-bed gas well network based on the determined well control range of the produced old well in the target coal-bed gas well network, wherein the range of the resources which are not used is the range, except the well control range of the produced old well, in the defined range of the target coal-bed gas well network, and the overlapping range of the well control range of the deployed new well and the well control range of the adjacent produced old well does not exceed the target overlapping range.
10. An adjustment device for a coal bed methane well pattern, comprising a memory and a processor, the memory having stored therein a computer program operable on the processor, characterized in that the processor is configured to carry out the adjustment method for a coal bed methane well pattern according to any one of claims 1-8 when the computer program is executed.
11. A computer readable storage medium having stored therein at least one instruction, which is loaded and executed by a processor, to implement the method of adjusting a coal bed methane well pattern of any of claims 1-8.
CN202010544210.2A 2020-06-15 2020-06-15 Method and device for adjusting coalbed methane well pattern and computer readable storage medium Active CN113803029B (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN202010544210.2A CN113803029B (en) 2020-06-15 2020-06-15 Method and device for adjusting coalbed methane well pattern and computer readable storage medium

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
CN202010544210.2A CN113803029B (en) 2020-06-15 2020-06-15 Method and device for adjusting coalbed methane well pattern and computer readable storage medium

Publications (2)

Publication Number Publication Date
CN113803029A true CN113803029A (en) 2021-12-17
CN113803029B CN113803029B (en) 2023-08-22

Family

ID=78944128

Family Applications (1)

Application Number Title Priority Date Filing Date
CN202010544210.2A Active CN113803029B (en) 2020-06-15 2020-06-15 Method and device for adjusting coalbed methane well pattern and computer readable storage medium

Country Status (1)

Country Link
CN (1) CN113803029B (en)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN115450599A (en) * 2022-09-14 2022-12-09 中国地质大学（武汉） Method for determining fracturing target point interval of ground well for coal seam outburst prevention
CN115544851A (en) * 2022-11-23 2022-12-30 成都理工大学 Method for increasing energy of shale gas new well through fracturing and improving productivity of old well

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6729394B1 (en) * 1997-05-01 2004-05-04 Bp Corporation North America Inc. Method of producing a communicating horizontal well network
CN104695934A (en) * 2013-12-06 2015-06-10 中国石油天然气股份有限公司 Tight sandstone gas reservoir development well pattern optimization method
CN106285621A (en) * 2015-05-21 2017-01-04 中国石油化工股份有限公司 Method based on Multifactor Decision Making offshore oilfield new well in old district production capacity
CN205936553U (en) * 2016-08-25 2017-02-08 北京中能万祺能源技术服务有限公司 Raising output is transformed and novel coal seam gas well of formation to old well
CN111255431A (en) * 2018-11-30 2020-06-09 中国石油天然气集团有限公司 Method and device for optimizing small-curvature-radius directional well

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6729394B1 (en) * 1997-05-01 2004-05-04 Bp Corporation North America Inc. Method of producing a communicating horizontal well network
CN104695934A (en) * 2013-12-06 2015-06-10 中国石油天然气股份有限公司 Tight sandstone gas reservoir development well pattern optimization method
CN106285621A (en) * 2015-05-21 2017-01-04 中国石油化工股份有限公司 Method based on Multifactor Decision Making offshore oilfield new well in old district production capacity
CN205936553U (en) * 2016-08-25 2017-02-08 北京中能万祺能源技术服务有限公司 Raising output is transformed and novel coal seam gas well of formation to old well
CN111255431A (en) * 2018-11-30 2020-06-09 中国石油天然气集团有限公司 Method and device for optimizing small-curvature-radius directional well

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
李俊等: "樊庄区块井网调整技术研究与应用" *

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN115450599A (en) * 2022-09-14 2022-12-09 中国地质大学（武汉） Method for determining fracturing target point interval of ground well for coal seam outburst prevention
CN115544851A (en) * 2022-11-23 2022-12-30 成都理工大学 Method for increasing energy of shale gas new well through fracturing and improving productivity of old well
CN115544851B (en) * 2022-11-23 2023-08-15 成都理工大学 Method for increasing fracturing energy of new shale gas well and improving productivity of old shale gas well

Also Published As

Publication number Publication date
CN113803029B (en) 2023-08-22

Similar Documents

Publication Publication Date Title
US8095349B2 (en) Dynamic updating of simulation models
CN105134191B (en) The evaluation method of fine and close oil well reserves
CN111441758A (en) Shale oil gas dessert area prediction method and device
CN103336997B (en) Fine and close oil resource distribution Forecasting Methodology and prediction unit
CN113803029B (en) Method and device for adjusting coalbed methane well pattern and computer readable storage medium
CN109753671B (en) Oil reservoir accurate well position optimization method based on fish swarm algorithm
US20170175494A1 (en) Method of modelling hydrocarbon production from fractured unconventional formations
CN114737943A (en) Unconventional reservoir three-dimensional well pattern transformation method, device, equipment and medium
Chen et al. Improving Polymerflood Performance Via Streamline-Based Rate Optimization: Mangala Field, India
CN105447292A (en) Oil gas wildcat screening method
CN111986041A (en) Oil reservoir development method and device
CN113803044B (en) Method and system for integrally designing unconventional reservoir volume fracturing and well distribution scheme
CN111997581B (en) Heterogeneous oil reservoir development method and device and electronic equipment
CN115860266A (en) Shale gas/coal bed gas well productivity evaluation method and system and electronic equipment
CN112949025B (en) Staged fracturing design method, device and medium for horizontal well
CN111648753B (en) Hydraulic fracturing crack distribution optimization method for newly drilled horizontal well in water injection development well network
Ballin et al. New reservoir dynamic connectivity measurement for efficient well placement strategy analysis under depletion
CN114357766A (en) Long straight well section well pattern integral volume fracturing optimization design method
Pham et al. A Probability Approach to Development of a Large Carbonate Reservoir with Natural Fractures and Stratiform Super-Permeabilities
CN114856500B (en) Intelligent design method and system for gas extraction drilling
Zolotukhin et al. Selection of the Best Development Scenario for the Thin Oil Rim with Reservoir Pressure Maintenance System Involving Gas Injection into the Gas Cap. Case Study: West Masssoyakha PK 1-3 Horizon.
Dehdari et al. Well spacing and recovery optimization of one of Iranian oil fields by using streamline and reservoir simulation
CN115126469B (en) Method and computer equipment for optimizing deployment of coal bed gas well pattern
CN114810047A (en) Method, device and equipment for determining borehole trajectory in oil reservoir stratum and storage medium
CN113006781B (en) Horizontal well group yield prediction method and device, computer equipment and storage medium

Legal Events

Date Code Title Description
PB01 Publication
PB01 Publication
SE01 Entry into force of request for substantive examination
SE01 Entry into force of request for substantive examination
GR01 Patent grant
GR01 Patent grant