Horizontal well staged plugging method

Abstract

The present application relates to the technical field of horizontal well segmented plugging, and particularly relates to a horizontal well segmented plugging method, which comprises the following steps: obtaining absorption information of a horizontal well formation; dividing the horizontal well formation into multiple separated segments based on the absorption information of the horizontal well formation; determining the composition of a plugging agent for each separated segment according to the absorption information of each separated segment; and injecting the corresponding plugging agent into each separated segment. The method makes the plugging of horizontal well segments with different permeability more targeted, and makes the plugging effect more prominent. The method avoids the waste of plugging materials, time and labor caused by the poor plugging effect of the same plugging agent used in horizontal well segments with different permeability, and saves the cost.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of horizontal well segmented plugging, and particularly relates to a horizontal well segmented plugging method. BACKGROUND

[0002] In the process of performing the squeezing plugging operation on the horizontal well, due to the uneven permeability of the long well section of the horizontal well, problems such as horizontal section backflow, screen pipe completion, sand production and the like may occur, which leads to the fact that the squeezing operation cannot achieve the expected plugging effect, and even the plugging of the horizontal well fails, resulting in waste of materials, time and labor. Therefore, it is necessary to propose a horizontal well segmented plugging method to at least partially solve the problems existing in the prior art. SUMMARY

[0003] The embodiments of the present application aim to at least solve one of the technical problems existing in the prior art or related art.

[0004] To this end, the purpose of the embodiments of the present application is to provide a horizontal well segmented plugging method.

[0005] In order to achieve the above-mentioned purpose, the technical scheme of the embodiments of the present application provides a horizontal well segmented plugging method, comprising:

[0006] obtaining absorption information of a horizontal well formation;

[0007] dividing the horizontal well formation into a plurality of separated sections based on the absorption information of the horizontal well formation;

[0008] determining the composition of a plugging agent for each of the separated sections according to the absorption information of each of the separated sections;

[0009] injecting the corresponding plugging agent into each of the separated sections.

[0010] In addition, the horizontal well segmented plugging method in the above technical scheme provided by the embodiments of the present application can further have the following additional technical features:

[0011] In one technical scheme of the embodiments of the present application, the step of obtaining the absorption information of the horizontal well formation comprises:

[0012] putting a double-closing packer into the bottom layer of the horizontal well;

[0013] adjusting the distance between two first packers of the double-closing packer to a first preset value;

[0014] setting the two first packers and performing water squeezing operation on the formation section between the two first packers;

[0015] obtaining pressure information of the formation section according to the water squeezing operation result.

[0016] In a further aspect of the embodiments of the present application, the first preset value is 30-70 meters.

[0017] In a further aspect of the embodiments of the present application, the step of performing water squeezing operation on the stratum section between the two first packers of the double-closing packer after setting the two first packers includes:

[0018] moving the double-closing packer while keeping the distance between the two first packers of the double-closing packer at a preset value;

[0019] performing water squeezing operation on the stratum section between the two first packers of the moved double-closing packer.

[0020] In a further aspect of the embodiments of the present application, the step of dividing the stratum of the horizontal well into multiple separated sections based on the absorption information of the stratum of the horizontal well includes:

[0021] dividing the stratum section into multiple separated sections according to the obtained pressure information of the stratum section, wherein the maximum pressure difference between the stratum sections in each separated section does not exceed a second preset value.

[0022] In a further aspect of the embodiments of the present application, the second preset value is 2-3 MPa.

[0023] In a further aspect of the embodiments of the present application, the horizontal well section sealing method further includes:

[0024] sequentially feeding a guide cone, a flow restrictor, multiple packer assemblies and a releasing device into the horizontal well;

[0025] connecting the guide cone, the flow restrictor, the multiple packer assemblies and the releasing device through an injection pipe string;

[0026] adjusting the distance between every two adjacent packer assemblies in the separated sections to a third preset value.

[0027] In a further aspect of the embodiments of the present application, the number of the packer assemblies in the separated sections is selected according to the length of the separated sections.

[0028] In a further aspect of the embodiments of the present application, the third preset value is 50-70 meters.

[0029] In a further aspect of the embodiments of the present application, the packer assembly includes:

[0030] a second packer;

[0031] a ball sliding sleeve connected to the second packer through the injection pipe string.

[0032] In one of the technical solutions of the embodiment of the present application, the second packer is a hydraulic packer.

[0033] In one of the technical solutions of the embodiment of the present application, the ball drop diameter of the ball drop sleeve decreases in turn from the horizontal well bottom to the horizontal well mouth.

[0034] In one of the technical solutions of the embodiment of the present application, the step of injecting the corresponding plugging agent into each of the partition segments comprises:

[0035] Pressure is built up through the choke, and all the second packers are set;

[0036] The corresponding plugging agent is injected into the partition segment.

[0037] In one of the technical solutions of the embodiment of the present application, when the plugging agent in the partition segment reaches the designed amount, the partition segment is sealed and the adjacent partition segment is opened by putting the ball into the ball drop sleeve.

[0038] From the horizontal well bottom to the horizontal well mouth, the corresponding plugging agent is injected into each of the partition segments in turn.

[0039] In one of the technical solutions of the embodiment of the present application, the horizontal well section sealing method further comprises:

[0040] When all the partition segments are injected with the plugging agent, the injection string is pulled out of the horizontal well mouth through the release device.

[0041] Compared with the prior art, the present application has at least the following beneficial effects:

[0042] The present application divides the horizontal well formation into multiple partition segments based on the absorption information of the horizontal well formation, and determines the composition of the plugging agent for each partition segment according to the absorption information of each partition segment, and injects the corresponding plugging agent into each partition segment. This makes the sealing of different permeability sections of the horizontal well more targeted, and the sealing effect more prominent, avoiding the waste of sealing materials, time and labor caused by the poor sealing effect of the same plugging agent used in different permeability sections of the horizontal well, and saving costs.

[0043] The horizontal well section sealing method of the present application, other advantages, objects and features of the present application will be partially embodied through the following description, and partially understood by those skilled in the art through research and practice of the present application. BRIEF DESCRIPTION OF DRAWINGS

[0044] The above and / or additional aspects and advantages of the present application will become apparent and more readily appreciated from the following description, taken in conjunction with the following drawings of which:

[0045] Figure 1 A flowchart of a horizontal well segmented plugging method according to an embodiment of the present application is shown;

[0046] Figure 2 A structural diagram of a horizontal well segmented plugging device according to an embodiment of the present application is shown.

[0047] wherein, Figure 2 The correspondence between the reference signs in the drawings and the component names is as follows:

[0048] 110 guide cone, 120 choke, 130 second packer, 140 ball sliding sleeve, 150 releasing device, 160 injection string. DETAILED DESCRIPTION

[0049] In order to better understand the above technical solutions, the technical solutions of the embodiments of the present application will be described in detail below through the drawings and specific embodiments. It should be understood that the specific features in the embodiments of the present application and the specific embodiments are detailed descriptions of the technical solutions of the embodiments of the present application, but not limitations of the technical solutions of the present application. In the case of no conflict, the technical features in the embodiments of the present application and the specific embodiments can be combined with each other.

[0050] As Figure 1 shown, according to an embodiment of the present application, a horizontal well segmented plugging method is provided, comprising:

[0051] Step 101: Obtain the absorption information of the horizontal well formation. It can be understood that the absorption of the horizontal well formation is different due to different geographical locations, and the absorption information of the horizontal well formation includes the permeability information of the well section and the pressure information of the well section.

[0052] Step 102: Based on the absorption information of the horizontal well formation, the horizontal well formation is divided into multiple separate sections. It can be understood that after obtaining the absorption information of the horizontal well, the horizontal well formation is divided into multiple separate sections according to the absorption information, and the absorption of each adjacent separate section is obviously distinguished, and the absorption of the formation inside each separate section is similar.

[0053] Step 103: Determine the composition of the plugging agent for each separate section according to the absorption information of each separate section. It can be understood that different absorption separate sections need to be plugged with corresponding plugging agents, and specifically, the composition and proportion of each component of the corresponding plugging agent can be determined according to the specific absorption range of each separate section, so that the plugging agent is more targeted and the plugging effect of the horizontal well formation is more prominent.

[0054] Exemplarily, the bridging agents include a first bridging agent with a particle size of 3mm to 5mm and a second bridging agent with a particle size of 200μm to 900μm, and the mass concentration of the first bridging agent and the mass concentration of the second bridging agent are determined according to the specific absorption range value of the interval section.

[0055] Step 104: injecting the corresponding bridging agent into each interval section. It can be understood that after determining the corresponding bridging agent for each interval section, the corresponding bridging agent is injected into the interval section with different absorption, thereby completing the interval plugging operation of the horizontal well. The use of the same bridging agent in the horizontal well section with different permeability can avoid the waste of plugging materials, time and labor caused by poor plugging effect, thereby saving cost.

[0056] In some examples, the step of obtaining the absorption information of the horizontal well formation includes: placing a double-pack seal packer into the horizontal well formation; adjusting the distance between two first packers of the double-pack seal packer to a first preset value; setting the two first packers, and performing water squeezing operation on the formation section between the two first packers; and obtaining the pressure information of the formation section according to the water squeezing operation result.

[0057] It can be understood that the double-pack seal packer is provided with two first packers, and the distance between the two first packers can be adjusted. The double-pack seal packer is placed into the horizontal well formation, the distance between the two first packers is adjusted to a first preset value, the first packer is set by forming a pressure difference on both sides of each first packer, and the formation between the two first packers is sealed by the two first packers. The absorption information of the formation section between the two first packers is obtained according to the water squeezing operation result by performing water squeezing operation on the formation section between the two first packers, and the absorption information of the horizontal well formation includes the permeability information of the well section and the pressure information of the well section. The pressure sensor is used to detect the pressure of the formation section, and the absorption information of the formation section is indicated by obtaining the pressure information of the formation section.

[0058] In some examples, the first preset value is 30m to 70m.

[0059] In consideration of the efficiency of testing the absorption of the formation and the time cost of the test, in order to ensure the sealing effect of the formation between the two first packers and the accuracy of detecting the absorption of the formation, the distance between the two first packers is adjusted so that the distance between the two first packers is 30m to 70m.

[0060] In some examples, the step of performing water squeezing on the stratum section between the two first packers after setting the two first packers includes: moving the double packer while keeping the distance between the two first packers of the double packer at a preset value; and performing water squeezing on the stratum section between the two first packers of the moved double packer.

[0061] It can be understood that the length of the horizontal well is much longer than 70 meters. In order to test the absorbency of all positions of the stratum of the horizontal well, the distance between the two first packers needs to be adjusted to between 30 meters and 70 meters. The first packer is set by forming a pressure difference on both sides of each first packer. After the stratum between the two first packers is sealed, water squeezing is performed on the stratum between the first packers to obtain the absorbency information of the stratum section. Then, the two first packers are unsealed and moved to the next stratum section that needs to be tested for absorbency until the absorbency test of all positions of the stratum of the horizontal well is completed.

[0062] It can be understood that after the water squeezing of the stratum section is completed to test the absorbency of the stratum section, the adjacent stratum sections are tested in turn to avoid omission.

[0063] In some examples, the step of dividing the stratum of the horizontal well into multiple separated sections based on the absorbency information of the stratum of the horizontal well includes: dividing the stratum section into multiple separated sections according to the obtained pressure information of the stratum section, wherein the maximum pressure difference between the stratum sections in each separated section does not exceed a second preset value.

[0064] After the absorbency of all positions of the stratum of the horizontal well is tested, the stratum is divided into multiple separated sections according to the absorbency information of all tested stratum sections. The division criterion is that multiple stratum sections with a maximum pressure difference not exceeding a second preset value are set as one separated section. It can be understood that the minimum pressure difference between the stratum sections in adjacent separated sections should exceed the second preset value to ensure clear division. In this way, the stratum sections with small pressure difference values are grouped into one separated section, and a suitable plugging agent can be adjusted according to the pressure value of the separated section to plug all stratum sections in the separated section to ensure the plugging effect.

[0065] In some examples, the second preset value is 2 MPa to 3 MPa.

[0066] Under the premise of ensuring the plugging effect, the maximum pressure difference between the multiple stratum sections in each separated section does not exceed 2 MPa to 3 MPa. It can be understood that the minimum pressure difference between the stratum sections in adjacent separated sections should exceed 2 MPa to 3 MPa.

[0067] In some examples, one of the division segments has a length of 90 meters and contains two formation segments, one of which has a length of 40 meters and a pressure value of 1 Mpa, and the other has a length of 50 meters and a pressure value of 2.5 Mpa, the pressure difference between the two formation segments is 1.5 Mpa, and the second preset value is 2 Mpa, so the pressure difference between the two formation segments in the division segment does not exceed the second preset value.

[0068] The other division segment adjacent thereto has a length of 160 meters and contains three formation segments, one of which has a length of 60 meters and a pressure value of 5 Mpa, another has a length of 70 meters and a pressure value of 6 Mpa, and the other has a length of 30 meters and a pressure value of 7 Mpa, the maximum pressure difference of the division segment is 2 Mpa, and the second preset value is 2 Mpa, so the maximum pressure difference between the three formation segments in the division segment does not exceed the second preset value, and the minimum pressure difference between the two division segments is 2.5 Mpa, which exceeds the second preset value, and the boundary between the two adjacent division segments is clear.

[0069] In some examples, the horizontal well section sealing method further comprises: removing the double-shouldered packer from the horizontal well; sequentially feeding the guide cone 110, the flow restrictor 120, the plurality of packer assemblies, and the releasing device 150 into the horizontal well; connecting the guide cone 110, the flow restrictor 120, the plurality of packer assemblies, and the releasing device 150 through the injection string 160; and adjusting the distance between each adjacent two packer assemblies in the division segment to a third preset value.

[0070] Specifically, after the horizontal well formation is divided into a plurality of division segments according to the pressure information of the horizontal well formation, the double-shouldered packer is removed from the horizontal well formation, the guide cone 110, the flow restrictor 120, the plurality of packer assemblies, and the releasing device 150 are sequentially fed into the horizontal well, and the guide cone 110, the flow restrictor 120, the plurality of packer assemblies, and the releasing device 150 are connected through the injection pipe, so as to inject the corresponding plugging agent into the plurality of division segments.

[0071] The guide cone 110 is located at the bottom of the horizontal well and serves as a guide, the flow restrictor 120 is used to adjust the pressure in the formation and deliver the plugging agent, the packer assembly serves to seal the division segment, and the releasing device 150 is located at the wellhead and is used to inject the plugging agent into the division segment through the injection pipe.

[0072] It can be understood that after the guide cone 110, the flow restrictor 120, the plurality of packer assemblies, and the releasing device 150 are sequentially fed into the horizontal well, the positions of the plurality of packer assemblies need to be adjusted so that the distance between each adjacent two packer assemblies reaches a third preset value, so as to ensure the sealing effect of the division segment and reduce the sealing cost.

[0073] In some examples, the method further comprises: selecting the number of the packoff assemblies in the partition segment according to the length of the partition segment.

[0074] It can be understood that in some horizontal well formations, there is a long partition segment. Since the distance between each two adjacent packoff assemblies is a third preset value, the third preset value is less than the length of the partition segment, in order to make the partition segment have a good packoff effect, a certain number of packoff assemblies are needed to pack off the partition segment.

[0075] In some examples, the third preset value is 50-70 meters.

[0076] It can be understood that in order to ensure the packoff effect of the packoff assembly on the partition segment, the third preset value is set to 50-70 meters.

[0077] For example, in a formation of a horizontal well, there is a partition segment with a length of 160 meters, and the third preset value is 80 meters. Therefore, the distance between each two adjacent packoff assemblies is 80 meters. It can be seen that the partition segment is provided with three packoff assemblies, and the distance between each two packoff assemblies is 80 meters. The partition segment is packed into two formation segments by the three packoff assemblies, and the corresponding plugging agent of the partition segment can be injected into the two formation segments in sequence to complete the packoff of the partition segment, thereby improving the packoff effect.

[0078] In some examples, the packoff assembly comprises: a second packoff assembly 130; and a ball sliding sleeve 140, which is connected to the second packoff assembly 130 through the injection string 160.

[0079] Specifically, the packoff assembly is provided with the second packoff assembly 130 and the ball sliding sleeve 140, and the second packoff assembly 130 and the ball sliding sleeve 140 are connected through the injection string 160. It can be understood that the number of the second packoff assembly 130 and the ball sliding sleeve 140 is selected according to the length of the partition segment. By setting the two second packoff assemblies 130 in the partition segment, the formation segment between the two second packoff assemblies 130 can be packed off. When it is needed to open the formation segment to inject the plugging agent, the channel can be opened by throwing the ball sliding sleeve 140, so as to realize the segmented injection of the plugging agent.

[0080] In some examples, the second packoff assembly 130 is a hydraulic packoff assembly.

[0081] When a hydraulic packer needs to be set, pressure is applied to the injection string 160. The high-pressure hydraulic pressure acts on the inner cavity of the rubber sleeve through the pressure transmission gap inside the hydraulic packer. Under the action of the throttling pressure difference, the rubber sleeve expands, thereby sealing the annulus between the oil jacket and the sleeve. When the oil pressure is released and the oil jacket pressure is balanced, the rubber sleeve contracts back to its original state by its own elasticity, thus releasing the seal.

[0082] In some examples, the diameter of the ball-throwing sleeve 140 decreases sequentially from the horizontal wellhead to the horizontal well bottom.

[0083] Understandably, multiple ball-feeding sleeves 140 are installed in the formation of the horizontal well to release the second packer 130 connected to it, thereby injecting the corresponding plugging agent into all the partition sections. In order to ensure that the balls of all ball-feeding sleeves 140 can be put into the ball-feeding sleeves 140, the diameter of the balls of the ball-feeding sleeves 140 should decrease sequentially from the horizontal wellhead to the horizontal well bottom. In use, the ball with the smallest diameter is first put into the ball-feeding sleeve 140 closest to the horizontal well bottom, and then balls with gradually increasing diameters are put into the horizontal well in sequence, so that each ball-feeding sleeve 140 can work normally and ensure stability.

[0084] Understandably, the ball-launching sleeve 140 can be a normally closed ball-launching sleeve 140. Under normal conditions, setting the second packer 130 will seal the formation section between the second packers 130. When the ball is launched, the ball-launching sleeve 140 will open the channel near the horizontal wellhead and release the oil pressure to unseal the second packer 130 near the horizontal wellhead, so as to inject the plugging agent into the formation section between the second packers 130.

[0085] For example, in a horizontal well formation, two ball-feeding sleeves 140 are provided, wherein the ball-feeding diameter of the ball-feeding sleeve 140 near the bottom of the horizontal well is 38 mm, and the ball-feeding diameter of the ball-feeding sleeve 140 near the wellhead is 45 mm.

[0086] In some examples, the step of injecting the corresponding sealant into each of the aforementioned partitions includes: pressurizing the aforementioned throttle 120 to set all of the aforementioned second packers 130; and injecting the corresponding sealant into the aforementioned partition.

[0087] Specifically, after the guide cone 110, the choke 120, the plurality of second packers 130, the ball sliding sleeve 140 and the releasing device 150 are assembled in place, pressure is built up through the choke 120 to increase the pressure in the injection string, and the high pressure acts on the inner cavity of the rubber sleeve through the pressure transmission gap inside the second packer 130. Under the action of the throttling pressure difference, the rubber sleeve expands to seal the oil casing annulus, thereby setting all the second packers 130, so that the formation section between every two second packers 130 is sealed, and cooperating with the ball sliding sleeve 140, the lost circulation agent corresponding to each formation section is injected into the formation section, so as to complete the sealing of all the separated sections and ensure the sealing effect.

[0088] In some examples, the step of injecting the corresponding lost circulation agent into the separated section includes: when the amount of lost circulation agent in the separated section reaches the design amount, the separated section is sealed and the adjacent separated section is opened by putting the ball into the ball sliding sleeve 140; and from the horizontal well bottom to the horizontal wellhead, each separated section is sequentially injected with the corresponding lost circulation agent.

[0089] Specifically, after setting all the second packers 130, the corresponding lost circulation agent is injected into the formation section between the horizontal well bottom and the second packer 130 close to the horizontal well bottom through the choke 120. When the amount of lost circulation agent reaches the design amount, the ball sliding sleeve 140 connected to the second packer 130 is put into the ball, the passage close to the horizontal wellhead is opened while keeping the second packer 130 set, the oil pressure is released to unseal the second packer 130 adjacent to the second packer 130, the corresponding lost circulation agent of the separated section is injected into the formation section between the two second packers 130 through the releasing device 150, and from the horizontal well bottom to the horizontal wellhead, the corresponding lost circulation agent of the separated section is sequentially injected into the formation section between the second packers 130, so as to inject the corresponding lost circulation agent into all the separated sections. This makes the sealing of the horizontal well sections with different permeabilities more targeted and the sealing effect more prominent, avoids the waste of sealing materials, time and labor caused by the poor sealing effect of using the same lost circulation agent in horizontal well sections with different permeabilities, and saves costs.

[0090] For example, the releasing device 150 is a rubber plug type releasing device, which can seal the formation section through the rubber plug after the corresponding lost circulation agent of the separated section is injected into the formation section between the releasing device 150 and the second packer 130 closest to the releasing device 150 through the releasing device 150.

[0091] In some examples, the horizontal well section sealing method further includes: when all the separated sections are injected with the lost circulation agent, the injection string 160 is pulled out of the horizontal wellhead through the releasing device 150.

[0092] Specifically, after the operation of injecting the lost circulation material into all the separate segments is completed, the injection string 160 is separated from the guide cone 110, the choke 120, the plurality of second packers 130, the ball drop sliding sleeve 140 and the releasing device 150 respectively, the injection string 160 is pulled out of the horizontal wellhead through the releasing device 150 for subsequent repeated use, thereby saving cost.

[0093] In the description of the present application, the term "a plurality of" refers to two or more, unless otherwise explicitly limited, and the terms "upper", "lower", and the like indicate relative positions or orientation relationships based on the positions or orientation relationships shown in the drawings, and are only for the convenience of describing the present application and simplifying the description, and do not indicate or imply that the devices or elements referred to must have a particular orientation, be constructed and operated in a particular orientation, and therefore cannot be understood as limiting the present application; the terms "connection", "installation", "fixation" and the like should be understood broadly, for example, "connection" can be fixed connection, can also be detachable connection, or integral connection; can be directly connected, or indirectly connected through an intermediate medium. For those skilled in the art, the specific meanings of the above terms in the present application can be understood according to the specific circumstances.

[0094] In the description of the present application, the terms "one embodiment", "some embodiments", "a specific embodiment" and the like mean that the specific features, structures, materials or characteristics described in connection with the embodiment or example are included in at least one embodiment or example of the present application. In the present application, the illustrative description of the above terms does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described can be combined in any one or more embodiments or examples in a suitable manner.

[0095] The above only describes the preferred embodiments of the present application and is not intended to limit the present application. For those skilled in the art, the present application can have various modifications and changes. Any modification, equivalent replacement, improvement, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.

Claims

1. A method for segmented plugging of horizontal wells, characterized in that, include: Obtain absorbability information of horizontal well formations; The steps for obtaining the absorbent information of horizontal well formations include: Deploy a dual packer into the formation of the horizontal well; Adjust the distance between the two first packers of the dual-card packer to a first preset value; Set up two of the first packers and perform water squeezing operation on the formation section between the two first packers; Based on the results of the water squeezing operation, obtain the pressure information of the formation section; Based on the absorbency information of the horizontal well formation, the horizontal well formation is divided into multiple segments; The step of dividing the horizontal well formation into multiple segments based on the absorbency information of the horizontal well formation includes: Based on the obtained pressure information of the formation segment, the formation segment is divided into multiple partition segments, and the maximum pressure difference between the formation segments in each partition segment does not exceed a second preset value; The composition of the sealant for each of the partition segments is determined based on the absorbency information of each partition segment; Inject the corresponding sealing agent into each of the aforementioned segments.

2. The method for segmented plugging of horizontal wells according to claim 1, characterized in that, The first preset value is 30 meters to 70 meters.

3. The method for segmented plugging of horizontal wells according to claim 1, characterized in that, The steps of setting up the two first packers and performing water squeezing operation on the formation section between the two first packers include: While maintaining the distance between the two first packers of the dual-card packer at a first preset value, the dual-card packer is moved; A water-squeezing operation is performed on the formation section between the two first packers of the moved dual packer.

4. The method for segmented plugging of horizontal wells according to claim 1, characterized in that, The second preset value is 2MPa to 3MPa.

5. The method for segmented plugging of horizontal wells according to claim 1, characterized in that, Also includes: The dual packer is removed from the horizontal well; The guide cone, choke, multiple packer components, and release device are sequentially deployed into the horizontal well. The guide cone, the throttle, the plurality of the sealing assemblies, and the release device are connected via an injection string; The distance between any two adjacent sealing components in the partition segment is adjusted to a third preset value.

6. The method for segmented plugging of horizontal wells according to claim 5, characterized in that, Also includes: The number of the sealing components in the partition segment is selected according to the length of the partition segment.

7. The method for segmented plugging of horizontal wells according to claim 5, characterized in that, The third preset value is 50 meters to 70 meters.

8. The method for segmented plugging of horizontal wells according to claim 5, characterized in that, The sealing assembly includes: Second packer; The pitching slide is connected to the second packer via the injection string.

9. The method for segmented plugging of horizontal wells according to claim 8, characterized in that, The second packer is a hydraulic packer.

10. The method for segmented plugging of horizontal wells according to claim 8, characterized in that, From the horizontal wellhead to the horizontal well bottom, the diameter of the ball-throwing sleeve decreases sequentially.

11. The method for segmented plugging of horizontal wells according to claim 10, characterized in that, The step of injecting a corresponding sealing agent into each of the partition segments includes: The entire second packer is set by pressurizing the throttle; The corresponding sealing agent is injected into the dividing section.

12. The method for segmented plugging of horizontal wells according to claim 11, characterized in that, The step of injecting the corresponding sealing agent into the partition segment includes: When the sealing agent in the partition reaches the designed amount, the partition is sealed and the adjacent partition is opened by throwing the ball into the ball-throwing sleeve. From the bottom of the horizontal well to the top of the horizontal well, the corresponding plugging agent is injected sequentially into each of the partition sections.

13. The method for segmented plugging of horizontal wells according to claim 11, characterized in that, Also includes: When all the aforementioned sections have been injected with plugging agent, the injection string is pulled out of the horizontal wellhead using the release device.

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