CN109356560B - In-situ mining method and in-situ mining well pattern - Google Patents
In-situ mining method and in-situ mining well pattern Download PDFInfo
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- CN109356560B CN109356560B CN201811552953.3A CN201811552953A CN109356560B CN 109356560 B CN109356560 B CN 109356560B CN 201811552953 A CN201811552953 A CN 201811552953A CN 109356560 B CN109356560 B CN 109356560B
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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
- 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
- E21B43/305—Specific pattern of wells, e.g. optimizing the spacing of wells comprising at least one inclined or horizontal well
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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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/241—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
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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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
Abstract
The invention provides an in-situ mining method and an in-situ mining well pattern, wherein the method comprises the following steps: dividing a target reservoir into a plurality of to-be-mined intervals, wherein each interval to be mined has a preset thickness, and the intervals to be mined are arranged in the vertical direction; drilling two horizontal wells in the lowest stratum section to be mined, and drilling one horizontal well in each of the rest stratum sections to be mined; heating in the upper horizontal well in the lowermost interval to be mined and producing in the lower horizontal well in the lowermost interval to be mined; and heating the horizontal wells in each of the rest of the to-be-mined intervals in sequence, and mining the horizontal wells below and adjacent to the horizontal wells. The embodiment of the application provides an in-situ mining method and an in-situ mining well pattern, which can improve the heat exchange control volume to reduce heat loss and production cost.
Description
Technical Field
The invention relates to the field of in-situ exploitation of oil shale, in particular to an in-situ exploitation method and an in-situ exploitation well pattern.
Background
In-situ mining is to directly heat underground oil shale to crack the underground oil shale to generate oil gas, and finally to mine the oil gas through a production well. When the oil shale layer is heated to a certain temperature, organic matters in the oil shale are subjected to pyrolysis to generate liquid organic matters capable of seeping in the stratum.
Prior art methods for in situ recovery of oil shale using horizontal wells generally include a production well and an injection well above the production well. During exploitation, the target reservoir is heated through the injection well, and oil and gas are exploited through the production well. The method is suitable for oil shale reservoirs with relatively thin thickness. For thicker oil shale reservoirs, in the prior art, repeated heating is generally performed through an injection well, so that the thicker oil shale reservoirs can be pyrolyzed, but the reservoir close to the injection well is in a heated state even after pyrolysis is completed, and heat is wasted.
Therefore, there is a need for an in situ mining method that overcomes the above-mentioned deficiencies.
Disclosure of Invention
In view of the above, the embodiments of the present application provide an in situ mining method and an in situ mining well pattern that can increase the heat exchange control volume to reduce heat loss and production cost.
The above object of the present invention can be achieved by the following technical solutions: an in situ mining method comprising: dividing a target reservoir into a plurality of to-be-mined intervals, wherein each interval to be mined has a preset thickness, and the intervals to be mined are arranged in the vertical direction; drilling two horizontal wells in the lowest stratum section to be mined, and drilling one horizontal well in each of the rest stratum sections to be mined; heating in the upper horizontal well in the lowermost interval to be mined and producing in the lower horizontal well in the lowermost interval to be mined; and heating the horizontal wells in each of the rest of the to-be-mined intervals in sequence, and mining the horizontal wells below and adjacent to the horizontal wells.
As a preferred embodiment, when there are two intervals to be mined, the step of drilling two horizontal wells in the lowermost interval to be mined and drilling one horizontal well in each of the remaining intervals to be mined specifically includes: drilling two horizontal wells which are arranged in the vertical direction in a first interval to be mined, wherein the first interval to be mined is positioned at the bottom of the target reservoir; constructing a first crack communicated with the two horizontal wells in the first interval to be mined, and drilling the horizontal well above the first interval to be mined in a second interval to be mined, wherein the second interval to be mined is above the first interval to be mined; and constructing a second fracture in the second interval to be mined so as to enable the second fracture to be communicated with the horizontal well in the second interval to be mined and the horizontal well at the upper part in the first interval to be mined.
In a preferred embodiment, when the second interval to be mined is an oil shale formation, the horizontal well in the upper part of the first interval to be mined is located between the first interval to be mined and the second interval to be mined.
As a preferred embodiment, the step of drilling two horizontal wells arranged in the up-down direction in the first interval to be mined specifically includes: drilling a vertical well in the target reservoir so that the vertical well extends downwards into the first interval to be mined; and sidetracking two horizontal wells arranged in the vertical direction from the well hole of the vertical well to the first interval to be mined.
As a preferred embodiment, the step of drilling a horizontal well above the first interval to be mined in the second interval to be mined specifically includes: and sidetracking the horizontal well above the first interval to be mined from the well hole of the vertical well to the second interval to be mined.
As a preferred embodiment, the steps of heating in an upper horizontal well in the lowermost zone to be mined and producing in a lower horizontal well in the lowermost zone to be mined include: injecting high-temperature fluid into the horizontal well at the upper part in the first interval to be produced so that the high-temperature fluid can heat the first interval to be produced through the first fracture; mining through the horizontal well positioned below the first interval to be mined; injecting a high-temperature fluid into the horizontal well in the second interval to be mined so that the high-temperature fluid can heat the second interval to be mined through the second fracture; and mining through the horizontal well at the upper part in the first interval to be mined.
As a preferred embodiment, the high temperature fluid is one of superheated steam, critical water, air or nitrogen.
As a preferred embodiment, the step of injecting a high-temperature fluid into the horizontal well in the upper part of the first interval to be mined specifically includes: a first oil pipe is put into the vertical well, and a first annular space between the first oil pipe and the vertical well is sealed off, so that the first annular space is communicated with the horizontal well at the upper part in the first interval to be mined; the first oil pipe is communicated with the horizontal well positioned below the first interval to be mined; injecting the high-temperature fluid into the horizontal well at the upper part in the first interval to be mined through the first annular space; and producing the first interval to be produced through the first oil pipe.
As a preferred embodiment, the first annular space is sealed off by a first packer; wherein the first packer is disposed at a lower end of the first tubing; and the first packer is positioned between the two horizontal wells in the first interval to be mined.
As a preferred embodiment, before the step of running the first oil pipe in the vertical well, the method further comprises: running a second packer within the vertical well to seal a lower end of the vertical well.
As a preferred embodiment, the step of injecting a high temperature fluid into the horizontal well in the second interval to be produced specifically comprises: a second oil pipe is put into the vertical well, and a second annular space between the second oil pipe and the vertical well is sealed off, so that the second annular space is communicated with the horizontal well in the second interval to be mined; the second oil pipe is communicated with the horizontal well at the upper part in the first interval to be mined; injecting the high-temperature fluid into the horizontal well in the second interval to be mined through the second annular space; and exploiting the second to-be-exploited stratum section through the second oil pipe.
As a preferred embodiment, before the step of running the second oil pipe in the vertical well, the method further comprises: and a third packer is put into the vertical well to seal the vertical well, wherein the third packer is positioned between the two horizontal wells in the first interval to be mined.
In a preferred embodiment, the predetermined thickness is greater than 2m and less than 20 m.
As a preferred embodiment, when the thickness of the target reservoir is less than 20m, the number of the to-be-mined intervals is one.
An in situ production well pattern, comprising: the horizontal wells are arranged at intervals from bottom to top; two horizontal wells and a first crack communicated with the two horizontal wells are arranged in the lowest interval to be mined, and one horizontal well and a second crack communicated with the horizontal well in each interval to be mined and the adjacent horizontal well below are arranged in each other interval to be mined; wherein the to-be-mined stratum section is positioned in the target storage stratum.
The in-situ mining method and the in-situ mining well pattern provided by the application have the beneficial effects that: when the in-situ mining method is used in a thick reservoir, the thick reservoir is divided into a plurality of thin intervals to be mined, two horizontal wells are drilled in the lowest interval to be mined, one horizontal well is drilled in each of the other intervals to be mined, and finally the horizontal well at the upper part in the lowest interval to be mined is heated and mined in the horizontal well at the lower part in the lowest interval to be mined; and heating the horizontal wells in each of the rest of the to-be-mined intervals in sequence, and mining the horizontal wells below and adjacent to the horizontal wells. Compared with the prior art, through the condition of injecting well repeated heating, this application embodiment is through the mode that turns into thin reservoir with thick reservoir for can heat to every thin reservoir alone, so avoid the condition of repeated heating, and improve the even degree of being heated of heat transfer control volume and whole reservoir, thereby reduce calorific loss. And by means of mining each interval to be mined in sequence, the horizontal well in one interval to be mined can be mined and used by another interval to be mined, so that the service efficiency of each horizontal well is improved, and the production cost is reduced. Accordingly, embodiments of the present application provide an in situ mining method and an in situ mining well pattern that can increase heat exchange control volumes to reduce heat loss and production costs.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a flow diagram of an in situ mining method provided by one embodiment of the present invention;
FIG. 2 is a schematic illustration of an in situ mining method provided by one embodiment of the present invention;
FIG. 3 is another schematic illustration of an in situ mining method provided by one embodiment of the present invention;
FIG. 4 is a schematic illustration of an in situ production well pattern provided by one embodiment of the present invention.
Description of reference numerals:
11. the middle interlayer 13 and the first layer to be mined; 15. a second interval to be mined; 17. horizontal wells; 19. a first slit; 21. a second split; 23. a vertical well; 25. a first annular space; 27. a first oil pipe; 29. a first packer; 31. a second annular space; 33. a second oil pipe; 35. a second packer; 37. a third packer; 39. a target reservoir; 41. a gas-liquid separator; 43. a one-way valve; 45. a suction pump; 47. a first inlet; 49. an airflow outlet; 51. a liquid stream outlet; 53. a heater; 55. a high pressure pump; 57. an overburden; 59. an underlying rock formation; 61. a high temperature fluid; 63. producing a fluid; 65. and a fourth packer.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
Please refer to fig. 1 to 4. An embodiment of the present application provides an in-situ mining method, which may include: step S11: dividing the target reservoir 39 into a plurality of intervals to be mined, wherein each interval to be mined has a preset thickness, and the intervals to be mined are arranged in the vertical direction; step S13: drilling two horizontal wells 17 in the lowest section to be mined, and drilling one horizontal well 17 in each of the rest sections to be mined; step S15: heating in the upper horizontal well 17 in the lowermost interval to be mined and mining in the lower horizontal well 17 in the lowermost interval to be mined; and heating the horizontal wells 17 in the rest intervals to be mined in sequence, and mining the horizontal wells 17 below and adjacent to each other.
The technical scheme shows that: when the in-situ mining method is used in a thick reservoir, the thick reservoir is divided into a plurality of thin intervals to be mined, two horizontal wells 17 are drilled in the lowest interval to be mined, one horizontal well 17 is drilled in each of the other intervals to be mined, and finally, the upper horizontal well 17 in the lowest interval to be mined is heated and mined in the lower horizontal well 17 in the lowest interval to be mined; and heating in the horizontal well 17 in each of the remaining intervals to be mined in sequence, and mining in the adjacent horizontal well 17 below. Compared with the prior art, through the condition of injecting well repeated heating, this application embodiment is through the mode that turns into thin reservoir with thick reservoir for can heat to every thin reservoir alone, so avoid the condition of repeated heating, and improve the even degree of being heated of heat transfer control volume and whole reservoir, thereby reduce calorific loss. And the mode of mining each interval to be mined in sequence enables the horizontal well 17 in one interval to be mined and used by another interval to be mined, so that the service efficiency of each horizontal well 17 is improved, and the production cost is reduced.
As shown in fig. 1 and 2, in the present embodiment, step S11: the target reservoir 39 is divided into a plurality of intervals to be mined, wherein each interval to be mined has a predetermined thickness, and the plurality of intervals to be mined are arranged in the up-down direction. Specifically, first, a target reservoir 39 is selected based on a geological survey. In the present embodiment, the target reservoir 39 is an oil shale reservoir. The thickness of the oil shale mono-layer ore body is then determined, as well as the thickness and top-to-bottom depth of the interbed 11. For example, as shown in fig. 2, the target reservoir 39 is divided into a first interval to be produced 13 and a second interval to be produced 15, wherein the first interval to be produced 13 and the second interval to be produced 15 both have an interlayer 11 therein. The target reservoir 39 is finally segmented according to a predetermined thickness. The predetermined thickness is to ensure that the thickness of the interval to be mined is not too thin to avoid injection fluid cross-flow or flow into overburden 57 or overburden 59. The predetermined thickness is also used to ensure that the interval to be mined cannot be too thick to ensure the heating effect. Specifically, the predetermined thickness is greater than 2m and less than 20 m. In one embodiment, when the thickness of the target reservoir 39 is less than 20m, there is one interval to be produced. Compared with the prior art, through the condition of injection well repeated heating, the mode that this application embodiment passes through with thick reservoir transform to thin reservoir for can heat to every thin reservoir alone, so avoid the condition of repeated heating, and improve the even degree of being heated of heat transfer control volume and whole reservoir.
In the present embodiment, step S13: two horizontal wells 17 are drilled in the lowermost interval to be mined, and one horizontal well 17 is drilled in each of the remaining intervals to be mined.
In one embodiment, when there are two intervals to be produced, step S13: drilling two horizontal wells 17 in the lowest interval to be mined, and drilling one horizontal well 17 in each of the rest intervals to be mined, wherein the drilling method specifically comprises the following steps:
step S131: and drilling two horizontal wells 17 which are arranged in the up-down direction in the first interval to be produced 13, wherein the first interval to be produced 13 is positioned at the bottom of the target reservoir 39. As shown in fig. 2, one horizontal well 17 is drilled at the bottom of the first interval to be mined 13 and one horizontal well 17 is drilled at the upper part of the first interval to be mined 13. Preferably, when the second interval to be mined 15 is an oil shale formation, the upper horizontal well 17 in the first interval to be mined 13 is located between the first interval to be mined 13 and the second interval to be mined 15.
Further, step S131: drilling two horizontal wells 17 which are arranged in the vertical direction in the first interval to be mined 13, and specifically comprises the following steps:
step S1311: a vertical well 23 is drilled in the target reservoir 39 such that the vertical well 23 extends down into the first interval to be produced 13. Further, as shown in FIG. 2, a vertical well 23 is drilled to the bottom of the first interval to be produced 13. Further, the casing is lowered in the wellbore of the vertical well 23 and cemented between the casing and the wellbore. Preferably, the casing and the cementing cement may be made of materials resistant to high temperatures above 500 ℃ to prevent heat exchange between the high temperature fluid 61 and the non-target reservoir 39 as it flows in the wellbore, thereby reducing heat loss from the fluid in the wellbore.
Step S1313: two horizontal wells 17 which are arranged in the up-and-down direction are drilled from the well holes of the vertical well 23 to the first interval to be mined 13. Further, the first interval to be mined 13 is sidetracked by injecting high-pressure water jet into the vertical well 23, and two horizontal wells 17 which are arranged in the vertical direction are formed. The problem of the difficulty of whiplash encountered when drilling the horizontal well 17 through the whipstock is overcome by the high pressure water jet method. Further, the horizontal well 17 is an ultra-short branch well above the vertical well 23. Preferably, each horizontal well 17 has a length of 50m to 200 m. Preferably, each horizontal well 17 comprises a plurality of horizontal segments that are enclosed outside the vertical well 23. The number of the horizontal sections is 4 to 8. Further, the orientation, length, number and angle of the horizontal segments are determined according to the structural characteristics of the target reservoir 39 and the physical parameters of the oil shale, such as temperature, pressure, thermal conductivity, permeability and porosity.
Step S133: a first fracture 19 communicating two horizontal wells 17 is constructed in the first interval to be mined 13. As shown in fig. 2, in particular, the first fracture 19 is constructed in the zone between the wellbores of two horizontal wells 17. Further, a high velocity fluid may be injected into each horizontal well 17 to fracture the first interval to be mined 13. Further, parameters such as the width, length and number of the first fractures 19 should be determined according to the structural characteristics of the target reservoir 39 and physical parameters such as the temperature, pressure, thermal conductivity, permeability and porosity of the oil shale.
Step S135: and drilling a horizontal well 17 above the first interval to be mined 13 in the second interval to be mined 15, wherein the second interval to be mined 15 is above the first interval to be mined 13. As shown in fig. 3, a horizontal well 17 is drilled at the upper portion of the second interval 15 to be mined.
Further, step S135: drilling a horizontal well 17 above the first interval to be mined 13 in the second interval to be mined 15, and specifically comprises the following steps: and sidetracking a horizontal well 17 positioned above the first interval to be mined 13 from the borehole of the vertical well 23 to the second interval to be mined 15. Further, the second interval 15 to be mined is sidetracked by injecting high-pressure water jets into the vertical well 23 to form a horizontal well 17 above the first interval 13 to be mined. The problem of the difficulty of whiplash encountered when drilling the horizontal well 17 through the whipstock is overcome by the high pressure water jet method. Further, the horizontal well 17 is an ultra-short branch well above the vertical well 23. Preferably, the horizontal well 17 has a length of 50m to 200 m. Preferably, the horizontal well 17 comprises a plurality of horizontal segments that are enclosed outside the vertical well 23. The number of the horizontal sections is 4 to 8. Further, the orientation, length, number and angle of the horizontal segments are determined according to the structural characteristics of the target reservoir 39 and the physical parameters of the oil shale, such as temperature, pressure, thermal conductivity, permeability and porosity.
Step S137: and constructing a second fracture 21 in the second interval 15 to be mined so that the second fracture 21 is communicated with the horizontal well 17 in the second interval 15 to be mined and the upper horizontal well 17 in the first interval 13 to be mined. Specifically, as shown in fig. 3, the second fracture 21 is constructed in a region between the horizontal well 17 in the second interval to be mined 15 and the horizontal well 17 in the upper portion in the first interval to be mined 13. Further, a high velocity fluid may be injected into each horizontal well 17 to fracture the second interval 15 in a manner that will create a second fracture 21. Further, parameters such as the width, length and number of the second fractures 21 should be determined according to the structural characteristics of the target reservoir 39 and physical parameters such as the temperature, pressure, thermal conductivity, permeability and porosity of the oil shale.
In the present embodiment, step S15: heating in an upper horizontal well 17 in the lowest zone to be mined and mining in a lower horizontal well 17 in the lowest zone to be mined; and heating in the horizontal well 17 in each of the remaining intervals to be mined in sequence, and mining in the adjacent horizontal well 17 below.
In one embodiment, step S15: heating in the upper horizontal well 17 in the lowest zone to be mined and mining in the lower horizontal well 17 in the lowest zone to be mined, and the method specifically comprises the following steps:
as shown in fig. 2, step S151: injecting high-temperature fluid 61 into the horizontal well 17 at the upper part in the first interval to be mined 13, so that the high-temperature fluid 61 can heat the first interval to be mined 13 through the first fracture 19; and production is carried out through the horizontal well 17 located below in the first interval to be produced 13. Further, the high temperature fluid 61 is one of superheated steam, critical water, air, or nitrogen. Of course, the high temperature fluid 61 is not limited thereto, and may be other heat-carrying fluids or mixtures, which are not specified in this application. Further, a high-temperature fluid 61 can be injected into the horizontal well 17 at the upper part in the first interval to be mined 13 by adopting a constant-displacement injection or constant-pressure injection mode. Because the two horizontal wells 17 in the first interval to be mined 13 are communicated through the first fracture 19, when the high-temperature fluid 61 is injected into the horizontal well 17 at the upper part in the first interval to be mined 13, the high-temperature fluid 61 flows into the first fracture 19 under the action of the gravitational potential energy of the high-temperature fluid 61 and the pressure difference between the horizontal well 17 and the first interval to be mined 13, so that the high-temperature fluid is subjected to sufficient heat exchange with the first interval to be mined 13, and the high-temperature fluid 61 is cooled after the heat exchange and enters the horizontal well 17 below the first interval to be mined 13, so that oil and gas are mined. The oil shale in the first interval to be mined 13 is heated to generate chemical reaction to generate oil, gas and solid waste residues. The solid waste residues are left in the first interval to be mined 13, and oil, gas and cooled fluid enter a horizontal well 17 which is positioned below the first interval to be mined 13, so that the solid waste residues are mined.
Further, the step S151 of injecting the high-temperature fluid 61 into the horizontal well 17 at the upper part in the first interval to be mined 13 specifically includes:
step S1511: a first oil pipe 27 is put into the vertical well 23, and a first annular space 25 between the first oil pipe 27 and the vertical well 23 is sealed off, so that the first annular space 25 is communicated with the horizontal well 17 at the upper part in the first interval to be mined 13; the first oil pipe 27 is communicated with the horizontal well 17 positioned below in the first interval to be mined 13. I.e. the first annular space 25 forms a first path for injecting the high temperature fluid 61 with the upper horizontal well 17 in the first interval to be mined 13. The first oil pipe 27 and the horizontal well 17 below in the first interval to be mined 13 form a second channel for outputting oil and gas. The first passage is not in communication with the second passage so as to prevent the high temperature fluid 61 in the first passage from mixing with the produced fluid 63 in the second passage. Further, the first annular space 25 is sealed off by a first packer 29; wherein a first packer 29 is arranged at the lower end of the first tubing 27; and a first packer 29 is located between two horizontal wells 17 in the first interval to be mined 13.
Further, at step S1511: before the first oil pipe 27 is lowered into the vertical well 23, the method further comprises the following steps: a second packer 35 is run in the vertical well 23 to seal the lower end of the vertical well 23. Fluid in the vertical well 23 is thereby prevented from flowing into the overburden 59 below the first interval to be mined 13.
Step S1513: high temperature fluid 61 is injected into the upper horizontal well 17 in the first interval to be mined 13 through the first annular space 25. Thus, as shown in figure 2, the high temperature fluid 61 is able to flow through the first annular space 25 into the upper horizontal well 17 in the first interval to be mined 13 and through the first fracture 19 into the first interval to be mined 13.
Step S1515: the first interval to be produced 13 is produced through the first tubing 27. Specifically, the horizontal well 17 at the lower part in the first interval to be mined 13 can be pumped by the suction pump 45 on the first oil pipe 27 to mine the first interval to be mined 13. Further, after the horizontal well 17 at the lower part in the first interval to be mined 13 is pumped through the first oil pipe 27, the pumped fluid is separated through the gas-liquid separator 41 on the first oil pipe 27, and the separated oil gas is stored and transported to subsequent refining. And the separated cooling fluid flows into the heater 53 through a pipeline controlled by the one-way valve 43, is heated and then is pumped into the formation again for recycling.
Step S153: injecting high-temperature fluid 61 into the horizontal well 17 in the second interval 15 to be mined so that the high-temperature fluid 61 can heat the second interval 15 to be mined through the second cracks 21; and mining is performed through the upper horizontal well 17 in the first interval to be mined 13. Further, the high temperature fluid 61 is one of superheated steam, critical water, air, or nitrogen. Of course, the high temperature fluid 61 is not limited thereto, and may be other heat-carrying fluids or mixtures, which are not specified in this application. Further, the high-temperature fluid 61 can be injected into the horizontal well 17 in the second zone 15 to be mined by means of constant-displacement injection or constant-pressure injection. Because the horizontal well 17 in the second interval to be mined 15 is communicated with the horizontal well 17 at the upper part in the first interval to be mined 13 through the second fracture 21, when the high-temperature fluid 61 is injected into the horizontal well 17 of the second interval to be mined 15, the high-temperature fluid 61 flows into the second fracture 21 under the action of the gravitational potential energy of the high-temperature fluid 61 and the pressure difference between the horizontal well 17 and the second interval to be mined 15, so that the high-temperature fluid is subjected to sufficient heat exchange with the second interval to be mined 15, and the high-temperature fluid 61 is cooled after the heat exchange and enters the horizontal well 17 at the upper part in the first interval to be mined 13, so that oil and gas are mined. The oil shale in the second interval 15 to be mined is heated to generate chemical reaction to generate oil, gas and solid waste residue. The solid waste residues are left in the second interval 15 to be mined, and oil, gas and cooled fluid enter the horizontal well 17 at the upper part in the first interval 13 to be mined so as to be mined. When the second interval to be mined 15 is mined through the horizontal well 17 at the upper part in the first interval to be mined 13, the horizontal well 17 at the upper part in the first interval to be mined 13 can be used for a well injected with the high-temperature fluid 61 in the first interval to be mined 13 and can also be used for a well for mining in the second interval to be mined 15, so that the production cost is reduced.
Further, step S153: injecting high-temperature fluid 61 into the horizontal well 17 in the second interval 15 to be mined, which specifically comprises:
step S1531: a second oil pipe 33 is put into the vertical well 23, and a second annular space 31 between the second oil pipe 33 and the vertical well 23 is sealed off, so that the second annular space 31 is communicated with the horizontal well 17 in the second interval 15 to be mined; the second oil pipe 33 is communicated with the horizontal well 17 at the upper part in the first interval to be mined 13. I.e. the second annular space 31 forms a first path for injection of the high temperature fluid 61 with the horizontal well 17 in the second interval 15 to be mined. The second oil pipe 33 and the horizontal well 17 above the first interval to be mined 13 form a second channel for outputting oil and gas. The first passage is not in communication with the second passage so as to prevent the high temperature fluid 61 in the first passage from mixing with the produced fluid 63 in the second passage. Specifically, as shown in FIG. 3, the second annular space 31 is sealed off by a fourth packer 65.
As shown in fig. 3, further, in step S1531: before the second oil pipe 33 is lowered into the vertical well 23, the method further comprises the following steps: a third packer 37 is lowered in the vertical well 23 to seal the vertical well 23, wherein the third packer 37 is located between two horizontal wells 17 in the first interval to be mined 13. Thereby preventing fluids in the wellbore of the vertical well 23 from flowing into the formation below. Further, the first tubing 27 needs to be removed before running the third packer 37 in the vertical well 23.
As shown in fig. 3, step S1533: high temperature fluid 61 is injected through the second annular space 31 into the horizontal well 17 in the second interval 15 to be mined. Further, the high temperature fluid 61 is one of superheated steam, critical water, air, or nitrogen. Of course, the high temperature fluid 61 is not limited thereto, and may be other heat-carrying fluids or mixtures, which are not specified in this application. Further, the high-temperature fluid 61 can be injected into the horizontal well 17 in the second zone 15 to be mined by means of constant-displacement injection or constant-pressure injection.
Step S1535: the second interval 15 to be mined is mined through the second tubing 33. Specifically, the upper horizontal well 17 in the first interval to be mined 13 can be pumped by the suction pump 45 on the second oil pipe 33 to mine the second interval to be mined 15. Further, after the horizontal well 17 at the upper part in the first interval to be mined 13 is pumped through the second oil pipe 33, the pumped fluid is separated through the gas-liquid separator 41 on the second oil pipe 33, and the separated oil gas is stored and transported to subsequent refining. And the separated cooling fluid flows into the heater 53 through a pipeline controlled by the one-way valve 43, is heated and then is pumped into the formation again for recycling.
As shown in fig. 3, embodiments of the present application also provide an in situ production well pattern, comprising: a plurality of horizontal wells 17, the plurality of horizontal wells 17 being arranged at intervals from bottom to top; two horizontal wells 17 and a first crack 19 communicated with the two horizontal wells 17 are arranged in the lowermost interval to be mined, and one horizontal well 17 and a second crack 21 communicated with the horizontal well 17 in each interval to be mined and the adjacent horizontal well 17 below are arranged in each other interval to be mined; wherein the interval to be mined is located within the target reservoir 39. So that the heating can be carried out in the upper horizontal well 17 in the section to be mined at the bottom and the mining can be carried out in the lower horizontal well 17 in the section to be mined at the bottom; and heating in the horizontal well 17 in each of the remaining intervals to be mined in sequence, and mining in the adjacent horizontal well 17 below.
As shown in fig. 2, in one embodiment, two horizontal wells 17 arranged in the up-down direction and a first fracture 19 communicating with the two horizontal wells 17 are arranged in the first interval to be mined 13, and one horizontal well 17 positioned above the first interval to be mined 13 and a second fracture 21 communicating the horizontal well 17 in the second interval to be mined 15 with the horizontal well 17 in the upper portion of the first interval to be mined 13 are arranged in the second interval to be mined 15, wherein the first interval to be mined 13 is positioned at the bottom of the target reservoir 39, and the second interval to be mined 15 is positioned above the first interval to be mined 13.
As shown in fig. 2, embodiments of the present application also provide an in situ mining apparatus, including: the oil pipe is used for penetrating through the section 23 of the vertical well of the horizontal well 17, and an annular space can be formed between the oil pipe and the section 23 of the vertical well; and the packer is arranged on the oil pipe and is positioned between the adjacent horizontal wells 17, and the packer is used for sealing an annular space so as to enable the annular space and the oil pipe to be respectively communicated with one horizontal well 17.
When the device is used, oil pipes can be arranged in the vertical wells 23 of the target reservoir 39 in a penetrating mode and the annular space is sealed through the oil pipes, so that the annular space and the oil pipes are respectively communicated with one horizontal well 17, and therefore a first channel through which high-temperature fluid 61 flows and a second channel through which oil and gas are produced are formed independently.
As shown in fig. 2, in one embodiment, an in-situ mining device provided by the present application further includes: a gas-liquid separator 41, the gas-liquid separator 41 having a first inlet 47 and a gas flow outlet 49 for discharging gas and a liquid flow outlet 51 for discharging liquid, the first inlet 47 being in communication with the oil pipe and the liquid flow outlet 51 being in communication with the annular space. Thus, after being pumped through the oil pipe, the pumped fluid is separated by the gas-liquid separator 41 on the oil pipe, and the separated oil gas is stored and transported to the subsequent refining. And the separated cooling fluid flows into the heater 53 through a pipeline controlled by the one-way valve 43, is heated and then is pumped into the formation again for recycling.
As shown in fig. 2, a suction pump 45 is further provided between the oil pipe and the gas-liquid separator 41. So that the target reservoir 39 can be produced by the suction pump 45.
As shown in fig. 2, a heater 53 is further disposed between the liquid outlet 51 and the well bore of the vertical well 23. The cooling fluid may thus be heated by the heater 53 to meet the temperature requirements for pyrolysis of the target reservoir 39. Specifically, the liquid outlet 51 of the gas-liquid separator 41 is connected to a heater 53 through a pipeline, and the heater 53 is connected to the shaft of the vertical well 23 through a pipeline. Further, a high-pressure pump 55 is disposed between the heater 53 and the shaft of the vertical well 23. So that the heated fluid can be pumped into the annular space by the high pressure pump 55.
The above are only a few embodiments of the present invention, and those skilled in the art can make various changes or modifications to the embodiments of the present invention according to the disclosure of the application document without departing from the spirit and scope of the present invention.
Claims (15)
1. An in situ mining method, comprising:
dividing a target reservoir into a plurality of to-be-mined intervals, wherein each interval to be mined has a preset thickness, and the intervals to be mined are arranged in the vertical direction;
drilling two horizontal wells in the lowest stratum section to be mined, and drilling one horizontal well in each of the rest stratum sections to be mined;
heating in the upper horizontal well in the lowermost interval to be mined and producing in the lower horizontal well in the lowermost interval to be mined; and heating the horizontal wells in each of the rest of the to-be-mined intervals in sequence, and mining the horizontal wells below and adjacent to the horizontal wells.
2. The in-situ mining method according to claim 1, wherein when the number of the intervals to be mined is two, the step of drilling two horizontal wells in the lowermost interval to be mined and one horizontal well in each of the remaining intervals to be mined comprises the following steps:
drilling two horizontal wells which are arranged in the vertical direction in a first interval to be mined, wherein the first interval to be mined is positioned at the bottom of the target reservoir;
constructing a first fracture communicated with two horizontal wells in the first interval to be mined,
drilling a horizontal well above the first interval to be mined in a second interval to be mined, wherein the second interval to be mined is above the first interval to be mined;
and constructing a second fracture in the second interval to be mined so as to enable the second fracture to be communicated with the horizontal well in the second interval to be mined and the horizontal well at the upper part in the first interval to be mined.
3. The in situ mining method according to claim 2, wherein when the second interval to be mined is an oil shale formation, the horizontal well at the upper part in the first interval to be mined is located between the first interval to be mined and the second interval to be mined.
4. The in situ mining method according to claim 2, wherein the step of drilling two horizontal wells in the first interval to be mined in an up-down direction comprises:
drilling a vertical well in the target reservoir so that the vertical well extends downwards into the first interval to be mined;
and sidetracking two horizontal wells arranged in the vertical direction from the well hole of the vertical well to the first interval to be mined.
5. The in situ mining method of claim 2, wherein the step of drilling a horizontal well in a second interval to be mined above the first interval to be mined comprises:
and sidetracking the horizontal well above the first interval to be mined from the well hole of the vertical well to the second interval to be mined.
6. The in situ mining method of claim 2, wherein the steps of heating in an upper horizontal well in the lowermost panel and producing in a lower horizontal well in the lowermost panel comprise:
injecting high-temperature fluid into the horizontal well at the upper part in the first interval to be produced so that the high-temperature fluid can heat the first interval to be produced through the first fracture; mining through the horizontal well positioned below the first interval to be mined;
injecting a high-temperature fluid into the horizontal well in the second interval to be mined so that the high-temperature fluid can heat the second interval to be mined through the second fracture; and mining through the horizontal well at the upper part in the first interval to be mined.
7. The in situ mining method of claim 6, wherein: the high-temperature fluid is one of superheated steam, critical water, air or nitrogen.
8. The in situ mining method according to claim 6, wherein the step of injecting high temperature fluid into the horizontal well in the upper part of the first interval to be mined comprises the following steps:
a first oil pipe is put into the vertical well, and a first annular space between the first oil pipe and the vertical well is sealed off, so that the first annular space is communicated with the horizontal well at the upper part in the first interval to be mined; the first oil pipe is communicated with the horizontal well positioned below the first interval to be mined;
injecting the high-temperature fluid into the horizontal well at the upper part in the first interval to be mined through the first annular space;
and producing the first interval to be produced through the first oil pipe.
9. The in situ mining method of claim 8, wherein: packing the first annular space with a first packer; wherein the first packer is disposed at a lower end of the first tubing; and the first packer is positioned between the two horizontal wells in the first interval to be mined.
10. The in situ mining method of claim 8, further comprising, prior to the step of running a first tubing in the vertical well: running a second packer within the vertical well to seal a lower end of the vertical well.
11. The in situ mining method of claim 6, wherein the step of injecting a high temperature fluid into the horizontal well in the second interval to be mined comprises:
a second oil pipe is put into the vertical well, and a second annular space between the second oil pipe and the vertical well is sealed off, so that the second annular space is communicated with the horizontal well in the second interval to be mined; the second oil pipe is communicated with the horizontal well at the upper part in the first interval to be mined;
injecting the high-temperature fluid into the horizontal well in the second interval to be mined through the second annular space;
and exploiting the second to-be-exploited stratum section through the second oil pipe.
12. The in situ mining method of claim 11, further comprising, prior to the step of running a second tubing in the vertical well: and a third packer is put into the vertical well to seal the vertical well, wherein the third packer is positioned between the two horizontal wells in the first interval to be mined.
13. The in situ mining method of claim 1, wherein: the predetermined thickness is greater than 2m and less than 20 m.
14. The in situ mining method of claim 1, wherein: and when the thickness of the target reservoir is less than 20m, the number of the to-be-mined sections is one.
15. An in situ production well pattern, comprising:
the horizontal wells are arranged at intervals from bottom to top; two horizontal wells and a first crack communicated with the two horizontal wells are arranged in the lowest interval to be mined, and one horizontal well and a second crack communicated with the horizontal well in each interval to be mined and the adjacent horizontal well below are arranged in each other interval to be mined; wherein the to-be-mined stratum section is positioned in the target storage stratum.
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| CN110005390B (en) * | 2019-03-26 | 2021-04-30 | 中国石油天然气股份有限公司 | Method for in-situ conversion exploitation of shale oil gas by medium-low maturity shale oil large well spacing |
| CN110017125A (en) * | 2019-04-29 | 2019-07-16 | 苏州大学 | A kind of recovery method and system of shale gas |
| CN114251075B (en) * | 2020-09-23 | 2022-09-30 | 中国石油大学(北京) | Reservoir exploitation scheme determination method, device and equipment based on multi-target parameters |
| CN112593910B (en) * | 2020-12-10 | 2022-11-11 | 山西晋城无烟煤矿业集团有限责任公司 | Efficient mining method for broken low-permeability coal bed gas short horizontal well group |
| CN113846968A (en) * | 2021-10-12 | 2021-12-28 | 中国地质科学院勘探技术研究所 | Lateral drilling branch well heat taking device and method suitable for hot dry rock development |
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