Mechanical barriers are set in a single feeding process.

Abstract

An operation may require the use of multiple barriers to isolate the wellbore. A single-drive multi-barrier system can be deployed in the wellbore during a single drive string to position a first barrier at a first depth in the wellbore and a second barrier at a second depth above the first barrier in the wellbore. The first barrier is coupled to a first drive tool. A wellbore string segment connects the first drive tool to the second barrier. The second barrier is coupled to a second drive tool, which is coupled to the wellbore string. The second barrier is locked before the first barrier is independently positioned at the first depth to prevent its deployment before reaching the second depth. Positioning two barriers in a single drive increases the efficiency of the operation, including reducing the cost and time required to complete the operation.

Description

[0001] This application is a divisional application of the invention patent application filed on June 13, 2018, with international application number PCT / US2018 / 037289, Chinese national phase application number 201880092349.9, entitled "Setting a mechanical barrier in a single feed". Technical Field

[0002] This invention relates to setting up barriers, and more specifically, to setting up multiple barriers at two or more different depths in a wellbore during a single insertion. Background Technology

[0003] A wide variety of downhole tools, such as maintenance tools, can be used within the wellbore for hydrocarbon production and for repair or maintenance wells. In many situations, operations may require the introduction of multiple barriers into the borehole or wellbore and their placement at different depths within the wellbore to isolate portions of the wellbore or formation. Many operator and government regulations require at least two barriers to be installed in the wellbore. For example, several types of operations, including plugging and abandonment work for hydrocarbon production and blowout prevention, require the installation of multiple barriers in the wellbore. Typically, each barrier must be individually driven into the wellbore on a tool string such as drill pipe or tubing, and different tools may be required to unlock and set the barrier. For instance, a first barrier may be driven into the wellbore to a set depth via a tool string, set, and the tool string retrieved from the wellbore. A second barrier is connected to the tool string, driven into the wellbore, and set at a different set depth, and the tool string is retrieved back from the well. Each barrier installation requires at least two strokes along the wellbore, which increases equipment wear and tear and the risk of mechanical failure. Both of these factors contribute to increased total work completion time and total work cost, as well as increased safety risks to nearby personnel. Attached Figure Description

[0004] Figure 1 This is a cross-sectional view of a single-feed multi-barrier system in an operating environment according to one or more aspects of this disclosure.

[0005] Figure 2 This is a cross-sectional view of a single-feed multi-barrier system having deep-set barriers disposed in the operating environment, according to one or more aspects of this disclosure.

[0006] Figure 3 This is a cross-sectional view of a single-feed multi-barrier system having shallowly set barriers disposed in the operating environment, according to one or more aspects of this disclosure.

[0007] Figure 4A This is a schematic diagram of a shallowly installed barrier in an uninstalled position, which is fed into a multi-barrier system in a single operation according to one or more aspects of this disclosure.

[0008] Figure 4B This is a schematic diagram of a shallowly installed barrier in a single-pass delivery of a multi-barrier system, according to one or more aspects of this disclosure.

[0009] Figure 5A This is a schematic diagram of a deep-set barrier in a single-pass delivery of a multi-barrier system in an unset position, according to one or more aspects of this disclosure.

[0010] Figure 5B This is a schematic diagram of a deep-set barrier in a single-pass delivery of a multi-barrier system in a set position, according to one or more aspects of this disclosure.

[0011] Figure 6A This is a cross-sectional view of a locking slot assembly of a shallow-set barrier system in a locked position, according to one or more aspects of this disclosure.

[0012] Figure 6B This is a cross-sectional view of the locking slot assembly of a shallow-set barrier system in the unlocked position, according to one or more aspects of this disclosure.

[0013] Figure 7A This is a cross-sectional view of a locking slot assembly of a shallowly set barrier in a locked position, according to one or more aspects of this disclosure.

[0014] Figure 7B This is a cross-sectional view of a locking slot assembly of a shallowly set barrier in the unlocked position, according to one or more aspects of this disclosure.

[0015] Figure 8A This is a side view of a locking slot assembly of a shallowly set barrier in a locked position, according to one or more aspects of this disclosure.

[0016] Figure 8B This is a side view of a locking slot assembly of a shallowly set barrier in the unlocked position, according to one or more aspects of this disclosure.

[0017] Figure 9 This is a schematic side view of the spindle component and sliding locking component of a deep-set barrier system according to one or more aspects of this disclosure.

[0018] Figure 10 This is a schematic cross-sectional side view of the top adapter and retrieval cylinder components of a deep-set barrier system according to one or more aspects of this disclosure.

[0019] Figure 11 This is a partial cross-sectional schematic side view of a deep-set barrier system in a locked configuration according to one or more aspects of this disclosure.

[0020] Figure 12 This is a partial cross-sectional schematic side view of a deep-set barrier system in a connected and locked configuration according to one or more aspects of this disclosure.

[0021] Figure 13 This is a partial cross-sectional schematic side view of a deep-set barrier system in connection and unlock configuration according to one or more aspects of this disclosure.

[0022] Figure 14 This is a schematic side view of a partial cross-section of a deep-set barrier system in release and unlock configuration.

[0023] Figure 15 This is a schematic side view of a partial cross-section of a deep-set barrier system in a release configuration.

[0024] Figure 16 This is a schematic side view of a partial cross-section of a deep-set barrier system in a release configuration.

[0025] Figure 17 This is a flowchart illustrating a method for setting up a single-feed multi-barrier system according to one or more aspects of this disclosure. Detailed Implementation

[0026] In the following figures and description, similar portions are generally labeled with the same reference numerals. Specific embodiments are described and illustrated in the figures; it should be understood that this disclosure is to be regarded as an example of the principles of the invention and is not intended to limit the invention illustrated and described herein. It should be fully appreciated that the desired results can be achieved by employing the different teachings of the embodiments discussed throughout the text, either alone or in any suitable combination.

[0027] For certain downhole operations, barriers or isolation devices need to be deployed into the wellbore to isolate portions of the wellbore or formation. For example, blowout prevention (BOP) or abandonment of a well may require multiple barriers to be deployed into the wellbore to isolate portions of the wellbore or formation. Generally, for barriers deployed on downhole tools, once one barrier is installed, all barriers attached to the tubing string or wellbore string are installed. Operations requiring the installation of multiple barriers at different depths require multiple deployments into the wellbore. For example, a downhole tool including a barrier is deployed into the wellbore to a specified depth, and when that depth is reached, the barrier is installed. The downhole tool is retrieved, and another barrier is deployed into the wellbore on the same or a different downhole tool. Again, once the specified depth is reached, the barrier is installed, and the downhole tool is retrieved. Because deploying multiple barriers requires multiple deployments, placing multiple barriers at different depths takes a significant amount of time, increasing the overall cost of the operation and increasing the risk to nearby personnel due to repeated contact with equipment.

[0028] This invention provides increased efficiency for downhole operations that require the placement of multiple barriers or isolation devices within the wellbore to isolate portions of the wellbore or formation. Using a single deployment of downhole tools to provide a single-deployment multi-barrier system with multiple barriers that can be deployed within the wellbore reduces the need for multiple deployments. Deploying multiple barriers in a single deployment reduces equipment wear, reduces operation completion time, and increases safety by minimizing contact between nearby personnel and the required equipment. For example, a deep-deployment barrier can be connected to a retrieval tool, which in turn connects to a shallow-deployment barrier, which is also connected to the downhole tool's retrieval tool. Both the deep-deployment barrier and the shallow-deployment barrier can be deployed downhole in a single deployment because the shallow-deployment barrier remains locked until the deep-deployment barrier has been deployed.

[0029] Figure 1 This is a cross-sectional view of a single-pass multi-barrier system 150 in an operating environment 100 according to one or more aspects of this disclosure. The operating environment 100 includes a workover or drilling rig 106 (generally referred to herein as drill rig 106) located on or around a surface 104. Drill rig 106 extends through and around a wellbore 114, which penetrates subsurface formation 102. For example, drill rig 106 may be positioned and equipped for the discovery, exploration, production of hydrocarbons, or any combination thereof. In one or more embodiments, drill rig 106 may be positioned and equipped for well completion or abandonment (or both) or BOP (Break-Off) of wellbore 114. Wellbore 114 may extend into subsurface formation 102 at any angle or deviation from the surface 104.

[0030] Drilling rig 106 may include a derrick 108 and a drill platform 110, through which a wellbore string extends downward from drilling rig 106 into a wellbore 114. Drilling rig 106 may include a motor 116 for a drive mechanism 118. Mechanism 118 may include a winch, drum, crank, or any other means suitable for deploying and retrieving the wellbore string 120 into and from the wellbore. In one or more embodiments, wellbore 114 may include casing 128 or any other liner extending the length of wellbore 114 to form an annulus 126.

[0031] The wellbore string 120 may include one or more sections, including (but not limited to) one or more portions such as wellbore string section 120A and wellbore string section 120B. The wellbore string 120 may include drill pipe, tool strings, tubing strings, working strings, tubing, drill string, or any other tubing connected together to deploy one or more downhole tools within the wellbore 114, such as a single-use multi-barrier system 150. In one or more embodiments, the single-use multi-barrier system 150 is deployed in the annulus 126. Wellbore string section 120A may be connected to the single-use multi-barrier system 150. The wellbore string 120 may include any number of sections, segments, or lengths connected together to form the wellbore string 120. Any number of downhole tools may be connected to the wellbore string 120. The wellbore string 120 deploys the single-use multi-barrier system 150 to the desired depth within the wellbore 114. For example, wellbore string segment 120A may be connected to one or more other segments of wellbore string 120, and wellbore string segment 120B may be connected to one or more other segments of wellbore string 120. Any one or more segments of wellbore string 120 may be screwed or connected to any one or more other segments of wellbore string 120, one or more single-feed multi-barrier systems 150, one or more other downhole tools, or any combination thereof.

[0032] In one or more embodiments, a single-batch multi-barrier system 150 may include a deep-set barrier system 112B located at the distal end of the wellbore string 120 and a shallow-set barrier system 112A (collectively referred to as barrier system 112) above the deep-set barrier system 112B, a wellbore string segment 120A, and a wellbore string segment 120B. In one or more embodiments, a single-batch multi-barrier system 150 may include any number of barrier systems 112. Although in Figure 1The illustration shows a single wellbore string segment 120A and a single wellbore string segment 120B, but this disclosure contemplates any number of wellbore string segments 120A and 120B. A shallow-set barrier system 112A includes a delivery tool 122A and an isolation device 124A, such as a shallow-set barrier. A deep-set barrier system 112B includes a delivery tool 122B and an isolation device 124B, such as a deep-set barrier. In one or more embodiments, isolation devices 124A and 124B may include a bridge plug, a packer, a barrier valve, or any other isolation device. In one or more embodiments, wellbore string segment 120A is coupled to delivery tool 122A, and wellbore string segment 120B is coupled to delivery tool 122B and shallow-set barrier system 112A, wherein delivery tools 122A and 122B are collectively referred to as delivery tool 122. The feed tool 122A is connected to the isolation device 124A, and the feed tool 122B is connected to the isolation device 124B, wherein the isolation devices 124A and 124B are collectively referred to as isolation device 124. The wellbore string section 120B connects the isolation device 124A to the feed tool 122B.

[0033] Figure 2 This is a cross-sectional view of a single-feed multi-barrier system 150 having a deep-set barrier system 112B disposed in an operating environment 200, according to one or more aspects of this disclosure. The operating environment 200 is similar to the operating environment 100, except that the deep-set barrier system 112B has been removed from the wellbore string section 120B or disposed at a desired depth, specified depth, or selected depth in the wellbore 114.

[0034] Figure 3 This is a cross-sectional view of a single-feed multi-barrier system 150 having a shallow-set barrier system 112A disposed in an operating environment 300, according to one or more aspects of this disclosure. The operating environment 300 is similar to operating environments 100 and 200, except that the shallow-set barrier system 112A has been removed from the wellbore string section 120A or disposed at a desired depth, specified depth, or selected depth in the wellbore 114.

[0035] Although Figures 1 to 3 The operating environment depicted relates to a stationary drilling rig 106 for delivering a wellbore string 120 including a single-pass multi-barrier system 150 within a land-based wellbore 114. However, in alternative embodiments, a mobile workover rig, a wellbore service unit (such as a coiled tubing unit), or the like can be used to deliver the wellbore string 120 including the single-pass multi-barrier system 150 within the wellbore 114. It should be understood that the wellbore string 120 including the single-pass multi-barrier system 150 can be used alternatively in other operating environments, such as offshore wellbore operating environments. For example, the workover or drilling rig 106 may be located offshore and the wellbore 114 may be a subsea wellbore.

[0036] Figure 4A This is a schematic diagram of a shallowly positioned barrier or isolation device 124A in an un-positioned single-feed multi-barrier system (such as single-feed multi-barrier system 150) according to one or more aspects of this disclosure. The isolation device 124A is shown positioned or located in the annulus 126 formed by the casing 128 in the wellbore 114. In one or more embodiments, the isolation device 124A may be positioned or located in the uncased wellbore 114. The shallowly positioned barrier system 112A may include the isolation device 124A. In one or more embodiments, the isolation device 124A may include any one or more of a top connector 402A, a bottom connector 402B, a vent plate 412, a rubber element 410, an anchor 406, and a centralizer 404. In one or more embodiments, any one or more of the top connector 402A, bottom connector 402B, vent plate 412, rubber element 410, anchor 406, and centralizer 404 may be directly or indirectly coupled to the isolation device 124A. Top connector 402A connects isolating device 124A to delivery tool 122A. Bottom connector 402B connects isolating device 124A to one or more wellbore sections 120, downhole tools, or any other device. One or more anchors 406 may be included or connected to one or more protrusions 408. Centralizer 404 assists in maintaining the positioning of isolating device 124A in annulus 126.

[0037] Figure 4B This is a schematic diagram of a shallowly positioned barrier or isolation device 124A in a single-feed multi-barrier system (such as a single-feed multi-barrier system 150) in a set position according to one or more aspects of this disclosure. Figure 4B Similar to Figure 4A The difference is Figure 4A The rupture disc 412 in the casing has been ruptured to set the isolation device 124A. One or more anchors 408 are actuated such that one or more protrusions 408 secure the isolation device 124A to the casing 128 in the wellbore 114. In one or more embodiments, once the desired depth is reached, one or more protrusions 408 of one or more anchors 406 may be extended to contact or engage with the wellbore 114, annulus 126, casing 128, any other structure within the wellbore 114, or any combination thereof, to secure the isolation device 124A to the wellbore 114. The rubber element 410 is compressed to form a seal against the casing 128, thereby isolating a portion of the annulus 126. For example, the portion of the annulus 126 below the rubber element 410 is isolated from fluid flow from above the rubber element 410, and the portion of the annulus 126 above the rubber element is isolated from fluid flow from below the rubber element 410. This can be described according to the following description... Figures 6A to 8BAny one or more of the described embodiments are used to set up the isolation device 124A.

[0038] Figure 5A This is a schematic diagram of a deep-set barrier or isolation device 124B in an unset location within a single-pass multi-barrier system (such as a single-pass multi-barrier system 150) according to one or more aspects of this disclosure. The isolation device 124B is shown as being disposed or positioned within the annulus 126 formed by the casing 128 in a wellbore 114. In one or more embodiments, the isolation device 124B may be disposed or positioned within a casing-free wellbore 114. In one or more embodiments, the isolation device 124B may include any one or more of a top connector 502A, a bottom connector 502B, a pass tool 122B, a rubber element 510, an anchor 506, and a centralizer 504. In one or more embodiments, any one or more of the top connector 502A, the bottom connector 502B, the pass tool 122B, the rubber element 510, the anchor 506, and the centralizer 504 may be directly or indirectly coupled to the isolation device 124B. The top connector 502A is similar to... Figure 4A The top connector 402A. The top connector 504A connects the isolator 124B to the feed tool 122B. The bottom connector 504B connects the isolator 124B to one or more wellbore strings 120, downhole tools, or other devices, or terminates the isolator 124B. Figure 4A Similarly, one or more anchors 406 and one or more protrusions 408, one or more anchors 506 may include or be coupled to one or more protrusions 508. The centralizer 504 is similar to... Figure 4A The centralizer 404 also helps maintain the position of the isolation device 124B in the annulus 126.

[0039] Figure 5B This is a schematic diagram of a deep-set barrier or isolation device 124B in a single-feed multi-barrier system (such as a single-feed multi-barrier system 150) in a set position according to one or more aspects of this disclosure. Figure 5B Similar to Figure 5A The difference lies in that the isolation device 124B is in the set position. In one or more embodiments, once the desired depth is reached, one or more protrusions 508 of one or more anchors 506 can extend to contact or engage with the wellbore 114, annulus 126, casing 128, or any combination thereof. As stated above regarding Figure 4B As discussed below, the rubber element 510 is compressed to form a seal against the sleeve 128, thereby isolating a portion of the annulus 126. This can be seen from the following discussion... Figure 9 and Figure 10 Any one or more of the described embodiments are used to set up the isolation device 124B.

[0040] about Figure 6A and Figure 6B The locking slot assembly of the present invention is shown and generally indicated by the numeral 610. Figure 6A This is a cross-sectional view of the locking component 610 of a shallow-set barrier system 112A in a locked position, according to one or more aspects of this disclosure. Figure 6B This is a cross-sectional view of the locking assembly 610 in the unlocked position, according to one or more aspects of this disclosure. The locking assembly 610 is positioned adjacent to the downhole tool (in... Figure 7A The lower end of the downhole tool (shown in the image) is, for example, a... Figures 1 to 3 and Figure 4A The feed tool 122A. The shallow setting barrier system 112A can be connected to a toolchain (not shown). For example, such as... Figure 1 As illustrated, the feed tool 122A can be connected to the wellbore string 120. The entire tool string or wellbore string 120 can be located within the wellbore, such as a... Figures 1 to 4B Wellbore 114. The wellbore may consist of a casing (not shown) (such as...) Figures 1 to 4B The sleeve 128) is defined and can be vertical, horizontal or deviated from any degree.

[0041] Locking assembly 610 is illustrated at the distal end of shallow-set barrier system 112A. Shallow-set barrier system 112A may include, be attached to, or otherwise coupled to an internal actuation mandrel 614, which may be connected to or coupled to wellbore string 120. Locking assembly 610 may include actuation mandrel 614, which is attached at its lower end to bottom adapter 616. At least a portion of actuation mandrel 614 and bottom adapter 616 may be located within fluid chamber housing 618, lock 620, or both. Fluid chamber housing 618 and lock 620 may be removably attached to each other, fixedly attached, or even integrally formed. Alternatively, fluid chamber housing 618 and lock 620 may be separate.

[0042] At least one fluid chamber 622 may be located between the actuating spindle 614 and the lock 620. The fluid chamber 622 may be connected via one or more seals 624 to a vent plate 626 (such as...) located in the lock 620. Figure 4AThe rupture disc 412 is sealed together with the fluid chamber 622. Atmospheric air can initially fill the fluid chamber 622. As the shallow-set barrier system 112A is lowered into the wellbore, the hydrostatic pressure outside the shallow-set barrier system 112A increases. Once the hydrostatic pressure reaches a predetermined value, the rupture disc 626 can rupture. After the rupture disc 626 has ruptured, fluid outside the shallow-set barrier system 112A will enter the shallow-set barrier system 112A through the port 628 formed in the shallow-set barrier system. The resulting increase in pressure within the fluid chamber 622 will cause the fluid chamber 622 to expand (e.g., ...). Figure 6B (As shown in the diagram). This expansion causes the lock 620 to move longitudinally relative to the actuation spindle 614, thereby "unlocking" the locking assembly 610. The locking assembly 610 is locked and unlocked independently of the sliding lock 950 of the deep-set barrier system 112B discussed below. Figure 8A and Figure 8B The locked and unlocked positions are shown separately.

[0043] Now see Figure 7A and Figure 7B An alternative implementation of the locking component 610 is shown therein. Figure 7A This is a cross-sectional view of the locking component 610 of a shallow-set barrier system 112A in a locked position, according to one or more aspects of this disclosure. Figure 7B This is a cross-sectional view of the locking assembly 610 of a shallow-set barrier system 112A in the unlocked position, according to one or more aspects of this disclosure. This embodiment does not have a blast-resistant plate 626. Instead, one or more shear pins 630 are present to prevent the lock 620 from moving before sufficient pressure is applied. A spring 632 may be included to hold the locking assembly 610 in the unlocked position. Although the spring 632 is shown as a coil spring, the spring 632 can be any biasing member. Similarly, the shear pin 630 can be a screw, a spring, or any other shearable member. In addition to using a blast-resistant plate 626, a spring 632, or both, Figure 7A and Figure 7B Implementation plan and Figure 6A and Figure 6B The implementation scheme works similarly. Increased pressure causes the lock 620 to move longitudinally relative to the actuating spindle 614, thereby unlocking the locking assembly 610 (e.g., Figure 7B (as shown in the image).

[0044] Figure 8A This is a side view of the locking component 610 of a shallowly set barrier system 112A in a locked position according to one or more aspects of the present invention. Figure 8BThis is a side view of the locking slot assembly of a shallow-set barrier system 112A in the unlocked position, according to one or more aspects of this disclosure. One or more lugs 634 extend from a lug rotator ring 636 into a continuous slot 638 in a sleeve 640, thereby providing a locking assembly 610. As previously discussed, pressure can cause the lock 620 to be unlocked. In the locked position, the locking portion 642 of the lock 620 occupies space within the slot 638, thereby holding the lug 634 in the wellhead position and preventing the lug 634 from moving relative to the slot 638. When the lock 620 moves downward due to increased pressure, the locking portion 642 moves out of the slot 638, thereby allowing the lug 634 to move relative to the slot 638 in the presence of an upward or downward force acting on the sleeve 640.

[0045] In the wellhead locking position, lock 620 is in the upward position, with lug 634 engaging the locking portion 642 of lock 620. As the tool string is lowered into the wellbore, locking assembly 610 will remain in the locked position. Figure 6A , Figure 7A and Figure 8A The locking position shown is such that the lock 620 prevents the lug rotator ring 36 from making relative longitudinal movement relative to the sleeve 640.

[0046] Once pressure is applied and locking component 610 is unlocked (as shown in the image) Figure 6B , 7B and Figure 8B As shown in the diagram, the locking assembly 610 can be actuated, allowing the lug rotator ring 636 to move longitudinally relative to the sleeve 640. In other words, the shallow setup barrier system 112A can be set by pushing down the wellbore string 120, the delivery tool 122A, or both (which lowers the lug 634). While any type of slot 638 can be used, the illustrated embodiment uses a J-slot, and specifically, a continuous J-slot is shown. Depending on the specific application and slot type, setting the tool may involve pushing the wellbore string 120 down multiple times. Therefore, when using a continuous J-slot, the delivery tool 122A can be set individually by up-and-down movement. This prevents the operator from prematurely cycling through the slot and setting the shallow setup barrier system 1122A.

[0047] For retrieval, simply pull the tool string or wellbore string 120 upwards out of the wellbore 114. This causes the lug 634 to re-engage the slot 638. Additionally, because the pressure outside the shallow-set barrier system 112A and therefore within the fluid chamber 622 is reduced, the lock 620 can be moved back to the locked position, thereby preventing any subsequent relative movement of the lug rotator ring 636 relative to the sleeve 640.

[0048] While the application of pressure is described above as a triggering event that allows lug 634 to move within slot 638, other events may also occur to allow lug 634 to move within slot 638. In this case, lock 620 may be configured to allow lug 634 to move within slot after the triggering event has occurred, provided predetermined conditions are maintained. For example, but not by means of restriction, the triggering event may be a timer reaching a predetermined value, and the predetermined condition may be that the timer has not yet reached a second predetermined value.

[0049] Figure 9 It is a barrier system based on one or more aspects of this disclosure (e.g., Figures 1 to 3 A schematic side view of the spindle component and sliding locking component of a deep-set barrier system 112B. The deep-set barrier system 112B may include a mechanical locking system 902. In one or more embodiments, the deep-set barrier system 112B may include a spindle extension 920, a spindle 930, a sliding lock 950, a spring spindle 960, and a spring housing 980, wherein... Figure 10 As described, the top adapter 910 and the retrieval tube 940 are removed. The mandrel 930 may include one or more sets of lugs 935 spaced circumferentially around the mandrel 930. In one embodiment, the mandrel 930 includes four (4) sets of lugs 935 spaced 90 degrees circumferentially around the mandrel 930, and each set of 938 includes ten (10) longitudinally spaced lugs 935.

[0050] Figure 10 This is a schematic cross-sectional side view of the top adapter 910 and retrieval tube 940 components of the deep-set barrier system 112B according to one or more aspects of the present invention. The top adapter 910 and retrieval tube 940 are disconnected from the remaining components of the deep-set barrier system 112B. The retrieval tube 940 includes one or more sets of circumferentially spaced inner lugs 945 surrounding the retrieval tube 940. In one embodiment, the number and position of the inner lugs 945 on the retrieval tube 940 directly correspond to the number and position of the outer lugs 935 on the mandrel 930. However, in other embodiments, different numbers of inner lugs 945 and outer lugs 935 may be provided, as long as the lugs 945, 935 interact to form a releasable connection.

[0051] Furthermore, the inner lug 945 and outer lug 935 are adapted to engage to support weight beneath the releasable connection. The size and number of the engaged lugs 945, 935, and more specifically, the total cross-sectional area of ​​the engaged lugs 945, 935, determine the amount of weight that the deep-set barrier system 112B (including (but not limited to) the delivery tool 122B) can support. In one embodiment, four (4) groups 948, 938 plus (10) lugs 945, 935 are provided on the retrieval tube 940 and the mandrel 930, respectively; the groups 948, 938 are spaced circumferentially at 90-degree intervals; each lug 945, 935 is approximately 1 / 2 inch wide and 1 / 4 inch high; and the deep-set barrier system 112B is adapted to support weights of hundreds of tons, for example, 500 tons. Assuming the lugs 945 and 935 are of the same size, the amount of weight that the deep-set barrier system 112B can support varies linearly with the number of lugs 945 and 935 provided. For example, if the embodiment described above includes only half the number of lugs 945 and 935, the deep-set barrier system 112B will be suitable for supporting a weight of 250 tons, and if the embodiment described above includes twice the number of lugs 945 and 935, the deep-set barrier system 112B will be suitable for supporting a weight of 1,000 tons. Similarly, assuming the same number of lugs 945 and 935, the amount of weight that the device 100 can support varies linearly with the size of the lugs 945 and 935 provided. For example, if the above-described implementation includes the same number of lugs 945 and 935 but the lugs 945 and 935 are only half the size, then device 100 will be suitable to support a weight of 250 tons, and if the above-described implementation includes the same number of lugs 945 and 935 but the lugs 945 and 935 are twice the size, then deep-set barrier system 112B will be suitable to support a weight of 1,000 tons.

[0052] As in Figure 9 and Figure 10 In the optimal depiction, to aid in aligning the retrieval tube 940 when lowering it on mandrel 930 to retrieve the deep-set barrier system 112B from wellbore 114, at least one set of lugs 938 935 includes a tapered upper surface 936 on the uppermost lug 935. This tapered upper surface 936 corresponds to the shape of at least one angled alignment key 949 on the retrieval tube 940. Therefore, the interaction between the tapered upper surface 936 on the uppermost lug 935 and the angled alignment key 949 guides the retrieval tube 940 into proper alignment, allowing for further lowering of the retrieval tube 940 on mandrel 930.

[0053] See again Figure 9In one embodiment, the mandrel 930 further includes one or more J-shaped slots 937 configured to receive at least one angled guide key 947 on the retrieval tube 940 when the retrieval tube 940 is lowered on the mandrel 930. The J-shaped slot 937 is shown as being... Figure 2 The sliding lock 950 partially covers the retrieval tube 940. When the retrieval tube 940 is lowered longitudinally on the fixed mandrel 930, the interaction between the J-shaped slot 937 and the angled guide key 947 imparts a rotation of less than 360 degrees in a first direction to the retrieval tube. In the embodiment shown herein, the interaction between the J-shaped slot 937 and the angled guide key 947 imparts a maximum rotation of 90 degrees to the retrieval tube 940. This rotation causes the inner lug 945 and the outer lug 935 to interact to form a releasable connection with the wellbore string 120. Thus, the J-shaped slot 937 acts as a rotation guide slot. Additionally, the J-shaped slot 937 may include a V-shaped inlet 939 corresponding to the shape of the angled guide key 947, thereby facilitating the entry of the guide key 947 into the J-shaped slot 937. In another embodiment of the deep-set barrier system 112B, the mandrel 930 does not include the J-shaped slot 937. In this embodiment, the retrieval tube 940 is lowered to a known position relative to the spindle 930 by engaging the shoulder, and then the retrieval tube 40 is rotated less than 360 degrees in a first direction relative to the spindle 930.

[0054] To disengage the inner lug 945 from the outer lug 935, a 45-degree rotation opposite to the first direction is applied from the surface of the wellbore 114 toward the wellbore string 120, thereby rotating the fishing barrel 940 relative to the mandrel 930. To ensure that the fishing barrel 940 is not over-rotated relative to the mandrel 930 during release, the mandrel 930 may include a rotation stop 934 extending between at least two of the outer lugs 935 to act as a barrier to prevent the inner lug 945 from reconnecting and re-engaging with the outer lug 935.

[0055] Figure 11 This is a partial schematic side view of a partial cross-section of a deep-set barrier system 112B in a locked configuration, according to one or more aspects of this disclosure. First, refer to the well entry operation sequence. Figure 11The deep-set barrier system 112B is depicted in a connected, locked, and weight-supported configuration. Specifically, the inner lug 945 on the retrieval tube 940 and the outer lug 935 on the mandrel 930 are shown interacting to form a releasable connection, with the upper surface 943 of the inner lug 945 abutting against the shoulder of the lower surface 993 of the outer lug 935, thus reflecting that the deep-set barrier system 112B is supporting weight. Furthermore, the guide key 947 on the retrieval tube 940 is shown disposed within a J-shaped slot 937 on the mandrel 930, with a sliding lock 950 in its uppermost locked position, thus covering a portion of the J-shaped slot 937. The sliding lock 950 is biased toward the locked position by a spring 970 disposed in a spring cavity 975 within a spring housing 980. In this locked position, the sliding lock 950 prevents the retrieval tube 940 from disengaging from the mandrel 930 during well entry.

[0056] Figure 12 Figure 5 is a partial schematic side view of a partial cross-section of a deep-set barrier system 112B in a connected and locked configuration according to one or more aspects of this disclosure. Once the deep-set barrier system (e.g., deep-set barrier system 112B) is lowered to a specified, desired, selected, or anticipated depth, a deep-set depth, forces can be applied from the surface 104 through the wellbore string 120 to manipulate the deep-set barrier system 112B, and in particular the isolation device 124B. Figure 5 depicts the deep-set barrier system 112B positioned to transmit forces from the wellbore string 120B to the isolation device 124B. When forces are applied through the wellbore string 120, the retrieval tube 940 is forced downward relative to the mandrel 930 until the lower surface 946 of the inner lug 945 abuts against the shoulder of the upper surface 996 of the outer lug 935, thereby transmitting forces to the isolation device 124B. Figure 12 As shown, the guide key 947 on the retrieval tube 940 has moved downward within the J-shaped slot 937 on the spindle 930, but the sliding lock 950 is still biased by the spring 970 to its uppermost locked position.

[0057] Figures 13 to 16 The sequence is depicted for unlocking the deep-set barrier system 112B and rotating the retrieval tube 940 less than 360 degrees relative to the mandrel 930 in the opposite direction to a first direction to allow removal of the top adapter 910 and the retrieval tube 940 from the wellbore 114. See first. Figure 13This figure is a partial schematic side view of a partial cross-section of a deep-set barrier system 112B in an engaged and disengaged configuration according to one or more aspects of this disclosure. After one or more isolation devices 124B have been actuated and positioned in the wellbore 114, the slide lock 950 can be forced downward to unlock the deep-set barrier system 112B by applying a differential pressure across the slide lock 950 against the bias spring 970. Because no fluid flows through the orifice 990 in the deep-set barrier system 112B, a differential pressure against the spring 970 can be applied across the slide lock 950 by pressurizing the annulus 126 formed between the deep-set barrier system 112B and the casing 128. When no pressure is applied to the annulus 126, the spring 970 expands to bias the slide lock 950 upward to the locked position. However, because the spring chamber 975 is in fluid communication with the device flow orifice 990 via port 965 in the spring spindle 960, once pressure is applied to the annulus 126, a differential pressure is generated across the sliding lock 950, thereby allowing the sliding lock 950 to overcome the bias of the spring 970 and move downwards. Figure 13 The unlocked position is shown, where the J-shaped slot 937 is fully visible. Therefore, in one embodiment, the sliding lock 950 is biased in response to pressure in the annulus 126.

[0058] In another embodiment, the slide lock 950 can be biased in response to a differential pressure generated by applying pressure to the flow orifice 990 instead of to the annulus 126. Similarly, because the spring chamber 975 is in fluid communication with the flow orifice 990 via a port 965 in the spring spindle 960, pressurizing the fluid within the flow orifice 990 creates a differential pressure across the slide lock 950, thereby allowing the slide lock 950 to overcome the bias of the spring 970 and move downwards into the annulus 126. Figure 13 The unlocked position is shown in the diagram. Therefore, in an alternative embodiment, the slide lock 940 is biased in response to tubing pressure.

[0059] Once the deep-set barrier system 112B is unlocked, and with the lower surface 946 of the inner lug 945 abutting against the shoulder of the upper surface 996 of the outer lug 935, a reverse rotation can be applied to the wellbore string 120, causing the top adapter 910 and the retrieval tube 940 to rotate relative to the mandrel 930 in the opposite direction to the first direction. This rotation will be less than 360 degrees, and in the embodiment described herein where the lugs 938, 948 of four (4) interacting groups are positioned circumferentially spaced 90 degrees apart, the rotation will be 45 degrees. Figure 14 As shown, because of this 45-degree opposite rotation, the inner lug 945 disengages from the outer lug 935 and moves to a position where it is not aligned with the outer lug 935 to reach the release position. Furthermore, because of the opposite rotation, the rotation stop 934 provides a barrier to prevent the inner lug 945 from reconnecting with the outer lug 935.

[0060] Once the retrieval tube 940 has been released from the spindle 930, the top adapter 910 and the retrieval tube 940 can be removed from the remaining components of the deep-set barrier system 112B, as follows: Figure 15 As shown in the image. After removing the top adapter 910 and the retrieval tube 940, as... Figure 16 As shown, the spindle extension 920, spindle 930, sliding lock 950, spring spindle 960, spring 970 and spring housing 980 are still connected to the isolation device 124B inside the wellbore 114.

[0061] When viewed in reverse order, Figures 11 to 16 The retrieval sequence of the deep-set barrier system 112B is also depicted, wherein the top adapter 910 and the retrieval tube 940 are retracted into the wellbore 114 to reconnect with the mandrel 930, in order to retrieve the deep-set barrier system 112B, including the isolation device 124B and the entry tool 122B, from the wellbore 114. See first. Figure 16 The image shows a partial schematic side view of a deep-set barrier system 112B connected to an isolation device 124B within the wellbore 114. The deep-set barrier system includes a mandrel extension 920, a mandrel 930, a sliding lock 950, a spring mandrel 960, a spring 970, and a spring housing 980. Because pressure has been removed from the annulus 126, the sliding lock 950 moves upward through the J-shaped slot 937 in response to the force of the spring 970.

[0062] Figure 15 This is a partial cross-sectional schematic side view of the deep-set barrier system 112B in a release configuration. When the top adapter 910 and the retrieval tube 940 are lowered on the mandrel extension 920 and mandrel 930, an angled alignment key 949 on the retrieval tube 940 engages the upper tapered surface 936 of the outer lug 935 on the mandrel 930. This engagement causes the retrieval tube 940 to rotate into proper alignment with the mandrel 390, such that the inner lug 945 of the assembly 948 will engage between the outer lugs 935 of the assembly 938 as the retrieval tube 940 continues to move downwards. Therefore, regardless of the position of the retrieval tube when it enters the wellbore 114, the upper tapered surface 936 on the outer lug 935 will interact with the angle on the alignment key 949 to properly align the retrieval tube 940 with the mandrel 930.

[0063] Furthermore, in one embodiment, the alignment key 949 has a longitudinal length exceeding the distance between the lugs 935 on the mandrel 930. Therefore, because the angled alignment key 949 will not engage between the two lugs 935 on the mandrel 930, the retrieval tube 940 and the mandrel 390 cannot form a partial connection. Instead, the retrieval tube 940 must be fully lowered on the mandrel 930 such that when the retrieval tube 940 is rotated to form a releasable connection, the lugs 945 of the group 948 on the retrieval tube 940 and the lugs 935 of the group 938 on the mandrel 930 are fully engaged, and the angled alignment key 949 is located below the lowermost mandrel lug 935.

[0064] Now see Figure 14 As the retrieval tube 940 continues to be lowered relative to the mandrel 930, the angled guide key 947 extends through the V-shaped opening 939 into the J-shaped slot 937, simultaneously mechanically engaging the tapered upper surface 952 of the sliding lock 50, thereby forcing the sliding lock 950 downwards against the force of the spring 970 to the unlocked position. Therefore, when the retrieval tube 940 is reattached to the mandrel 930, it is not necessary to apply pressure to the annulus 126 or the flow orifice 990 in response to differential pressure to cause the sliding lock 950 to move downwards against the spring 970. Instead, only the mechanical force of the angled guide key 947 acting on the tapered upper surface 952 of the sliding lock 950 is required. In an alternative embodiment, for example, the sliding lock 950 may be electromechanically actuated in response to a tripped switch, such as by retracting the sliding lock 950 using a downhole motor.

[0065] As the retrieval cylinder 940 continues to move downward in the longitudinal direction, the guide key 947 traverses the J-shaped slot 937, and the angled shape of the J-shaped slot 937 will further impart a maximum rotation of 990 degrees to the retrieval cylinder 940 in the first direction. Figure 13 As shown, when the guide key 947 moves toward the lowest point in the J-shaped slot 937, it causes the inner lug 945 of the retrieval tube 940 to rotate so as to interact with and engage with the outer lug 935 on the spindle 930. Once the guide key 947 no longer engages the sliding lock 950 to mechanically force the sliding lock downward, the sliding lock 950 will return to its original position in response to the biasing force of the spring 970. Figure 12 The topmost lock position is shown in the image.

[0066] The insertion tool 122B is now reconnected and locked, allowing the isolation device 124B to be retrieved from the wellbore 114. When the deep-set barrier system 112B is in... Figure 12In the configuration shown, the isolation device 124B can be released from the sleeve 128, thereby transferring weight to the interacting and engaging lugs 945, 935. This allows the retrieval tube 940 to be raised relative to the spindle 930, such that the upper surface 943 of the inner lug 945 abuts against the shoulder of the lower surface 993 of the outer lug 935, as shown. Figure 11 As shown. Still refer to Figure 11 When the deep-set barrier system 112B is in the weight-supported position, in one embodiment, the guide key 947 is located within the vertical portion of the J-shaped slot 937, such that the guide key 947 does not support any weight. Therefore, the guide key 947 does not need to have the same strength as the lugs 935, 945. Figure 11 As shown, the connected, locked, and weight-supported deep-set barrier system 112B is configured to retrieve the isolation device 124B from the wellbore 114.

[0067] Therefore, the deep-set barrier system 112B includes a releasable weight-support connection via interacting and engaging lugs 935, 945, which can be designed to support a large weight, such as 500 tons. Furthermore, such as when operating from a floating offshore drilling rig, the deep-set barrier system 112B facilitates easy release from the isolation device 124B by disengaging the lugs 935, 945 via a 45-degree opposite rotation of the retrieval cylinder 940 relative to the spindle 930. When reconnecting the lugs 935, 945, a 45-degree rotation in a first direction can be automatically imparted via the interaction of the guide key 947 and the J-shaped slot 937. The deep-set barrier system 112B may also include several safety features, such as: a sliding lock 950, which requires multiple actions to open at the wellhead position to prevent unintentional disconnection; an alignment key 949, which has the function of preventing partial connection between the lug 945 of the retrieval tube 940 and the lug 935 of the mandrel 930; and a rotation stop 934, which prevents unintentional reconnection during the release of the retrieval tube 940 from the mandrel 930.

[0068] Figure 17 This describes one or more aspects of the present disclosure for setting up a single-feed multi-barrier system (e.g., Figures 1 to 3 A flowchart of a method for a single-batch multi-barrier system 150. In step 1102, the single-batch multi-barrier system 150 is deployed in the wellbore 114. (See also: Regarding...) Figure 1As discussed, the single-feed multi-barrier system 150 may include a multi-barrier system 112, such as a shallow-positioned barrier system 112A and a deep-positioned barrier system 112B. In one or more embodiments, the distal end of the wellbore string 120 is coupled to the single-feed multi-barrier system 150. In one or more embodiments, each component of the single-feed multi-barrier system 150 is coupled to the wellbore string 120 one by one as the wellbore string 120 is fed into the wellbore 114. For example, when the wellbore string 120 is lowered into the wellbore 114, the deep-positioned barrier system 112B is coupled to the wellbore string segment 120B, the wellbore string segment 120B is coupled to the shallow-positioned barrier system 112A, the shallow-positioned barrier system 112A is coupled to the wellbore string segment 120A, and the wellbore string segment 120A is coupled to one or more other segments of the wellbore string 120. Initially, the single-push multi-barrier system is deployed with the shallow-set barrier system 112A and the deep-set barrier system 112B in a locked configuration, ensuring that isolation devices 124A and 124B are not inadvertently deployed during the deployment of the single-push multi-barrier system 150 to the designated, required, or desired depth in the wellbore 114. For example, as described above... Figure 6A , Figure 7A and Figure 8A The discussion focuses on locking the shallow-set barrier system 112A, and can be described as above regarding... Figure 9 and Figure 10 The discussion pertains to locking the deep-set barrier system 112B. In one or more embodiments, the shallow-set barrier system 112A includes a hydraulic locking feature that prevents the isolation device 124A from being set before a specified hydrostatic pressure is reached at a specified shallow-set depth, while the deep-set barrier system 112B includes a mechanical locking system 902 that prevents the isolation device 124B from being set before a specific deep-set depth has been reached.

[0069] At step 1106, it is determined whether the deployment depth of the deep deployment barrier system 112B has been reached. The deployment depth may be based on one or more parameters of the formation 102, the wellbore 114, or any other parameters or combinations thereof. The depth of each component of the single-drive multi-barrier system 150 when deployed into the wellbore 114 can be determined by any one or more techniques used to determine the depth in the wellbore 114. For example, the length of each segment of the wellbore string 120 and any downhole tools attached to the wellbore string is known, such that the depth of the distal end of the wellbore string 120 or any portion along the wellbore string 120 is known when the wellbore string 120 is driven into the wellbore 114.

[0070] At step 1112, once the depth of the deep-set barrier system 112B has been reached, the deployment of the wellbore string 120 is stopped or suspended, and the isolation device 124B (e.g., a deep-set barrier) is installed. For example, the deployment of the barrier system 112B can be stopped, suspended, or paused. Figure 1 The motor 116 and winch 118 are actuated. Because the shallow-set barrier system 112A remains locked during the deployment of the single-feed multi-barrier system 150, the isolation device 124B can be set independently of the isolation device 124A. For example, it can be based on the above regarding Figure 9 and Figure 10 Any one or more embodiments discussed herein shall be used to set up isolation device 124B, while isolation device 124A is as described above regarding Figure 6A , Figure 7A and Figure 8A The discussion remains locked. In one or more embodiments, the isolation device 124B is mechanically provided when the wellbore string 120 is rotated, moved up and down, or otherwise manipulated.

[0071] At step 1118, the deep-set barrier system 112B is disconnected from the wellbore tubing section 120B. For example, as described below... Figures 13 to 16 As discussed, the insertion tool 122B can be disconnected from the wellbore string section 120B. In one or more embodiments, the insertion tool 122B can be mechanically, hydraulically, or mechanically and hydraulically disconnected from the wellbore string section 120B.

[0072] In step 1124, once the deep-set barrier system 112B has been disconnected from the wellbore string 120, the wellbore string 120 is retracted or taken up to position or position the shallow-set barrier system 112A at a specified, defined, desired, or selected depth (shallow setting depth). For example, an actuable... Figure 1 The motor 116 and winch 118 are used to pull, retrieve, or retract one or more sections of the wellbore string 120 from the wellbore 114.

[0073] At step 1130, it is determined whether the shallow deployment depth of the barrier system has been reached. This deployment depth may be based on one or more parameters of the formation 102, the wellbore 114, or any other parameters or combinations thereof. As discussed above regarding step 1106, the depth of each component of the single deployment of the multi-barrier system 150 during retraction, retrieval, collection, or pulling from the wellbore 114 can be determined using any one or more techniques for determining the depth within the wellbore 114.

[0074] At step 1136, once the installation depth of the shallow-set barrier system 112B has been reached, the deployment of the wellbore string 120 is stopped or halted, and the isolation device 124A (e.g., the shallow-set barrier) is installed. For example, the deployment of the barrier system 112B can be stopped, halted, or suspended. Figure 1 The actuation of the motor 116 and the winch 118. In one or more embodiments, this can be achieved according to the above description regarding... Figure 6B , Figure 7B and Figure 8B The isolation device 124A may be configured in any one or more of the embodiments discussed above. In one or more embodiments, the isolation device 124A is configured by applying a fractured disc to the wellbore 114 (e.g., Figure 4A Explosion-proof sheet 412 or Figure 6A The annular pressure of the explosion-proof disc 626) to reduce the J-shaped slot (e.g., Figure 8A and Figure 8B The slot 638) is unlocked, thereby setting the isolation device 124A.

[0075] At step 1142, once the isolation device 124A has been installed, the delivery tool 122A is disconnected from the wellbore string section 120A. For example, the delivery tool 122A can be hydraulically, mechanically, or both hydraulically and mechanically disconnected from the wellbore string section 120A. In one or more embodiments, the shallow-positioned barrier system 112A, including the delivery tool 122A, is disconnected from the wellbore string section 120A in a manner similar to that discussed above with respect to the deep-positioned barrier system 112B.

[0076] At step 1148, any remaining section of the wellbore string 120 is retracted, retrieved, or pulled out from the wellbore 114. Once the wellbore string 120 has been pulled out from the wellbore 114, one or more additional steps can be initiated to complete the given operation.

[0077] Therefore, the present invention is well-suited to achieving the stated objectives and advantages, as well as those inherent therein. The specific embodiments disclosed above are merely illustrative, as the invention can be modified and practiced in different but equivalent ways that will be apparent to those skilled in the art who benefit from the teachings herein. Furthermore, it is not intended to limit the details of the constructions or designs shown herein beyond what is described in the appended claims. It is therefore apparent that changes or modifications may be made to the specific illustrative embodiments disclosed above, and all such changes are considered to be within the scope of the invention. Moreover, the terms in the claims have their ordinary meaning unless otherwise explicitly and clearly defined by the patent holder.

[0078] In one or more embodiments, a method of setting up a single-entry multi-barrier system includes: deploying the single-entry multi-barrier system on a wellbore string in a formation, wherein the single-entry multi-barrier system includes a deep-set barrier system at a distal end of the wellbore string and a shallow-set barrier above the deep-set barrier system; determining whether the single-entry multi-barrier system has reached a first depth in the wellbore; setting up a first isolation device for the deep-set barrier system, wherein the shallow-set barrier system includes a blast-proof disc that prevents lugs from moving within a series of J-shaped slots during the setting up of the first isolation device to prevent the setting up of the shallow-set barrier system; disconnecting the deep-set barrier system from the wellbore string; retrieving the wellbore string to a second depth; setting up a second isolation device for the shallow-set barrier system; and disconnecting the shallow-set barrier system from the wellbore string. In one or more embodiments, setting up the second device includes: rupturing the blast-proof disc; allowing the lugs to move within the series of J-shaped slots; and rising and pushing downwards on the wellbore string. In one or more embodiments, the first isolation device is coupled to a first delivery tool, and disconnecting the deep-set barrier system from the wellbore string includes disengaging the first delivery tool from the wellbore string. In one or more embodiments, the shallow-set barrier system is coupled to a second delivery tool, wherein the second delivery tool is coupled to the wellbore string, and disconnecting the shallow-set barrier system from the wellbore string includes disengaging the second delivery tool from the wellbore string. In one or more embodiments, the method further includes extending one or more first protrusions of one or more first anchors of the deep-set barrier system to contact at least one of the wellbore, an annulus disposed within the wellbore, and casing disposed within the wellbore. In one or more embodiments, the method further includes extending one or more second protrusions of one or more second anchors of the shallow-set barrier system to contact at least one of the wellbore, an annulus disposed within the wellbore, and casing disposed within the wellbore. In one or more embodiments, the method further includes maintaining the positioning of the first isolation device in the annulus of the wellbore via a first centralizer. In one or more embodiments, the method further includes maintaining the positioning of the second isolation device in the annulus of the wellbore via a second centralizer. In one or more embodiments, at least one of the first setup depth and the second setup depth is based on one or more formation parameters. In one or more embodiments, the method further includes retrieving the wellbore string from the wellbore.

[0079] In one or more embodiments, a single-deployment multi-barrier system includes: a deep-set barrier system, wherein the deep-set barrier system includes a first isolation device and a first delivery tool, wherein the first delivery tool is coupled to a first portion of a wellbore string; a shallow-set barrier system, wherein the shallow-set barrier system includes a second isolation device and a second delivery tool, wherein the second delivery tool is coupled to a second portion of the wellbore string; and a locking assembly for the shallow-set barrier system, wherein the locking assembly is locked and unlocked independently of the deep-set barrier system. In one or more embodiments, the locking assembly includes a blast-proof plate that prevents a lug from moving within a series of J-shaped slots during deployment of the first isolation device to prevent deployment of the shallow-set barrier system. In one or more embodiments, the lug moves within the series of J-shaped slots to deploy the second isolation device upon rupture of the blast-proof plate. In one or more embodiments, the deep-set barrier system further includes a first delivery tool coupled to the first isolation device and the wellbore string, wherein the first delivery tool is disconnected from the wellbore string to deploy the first isolation device and reconnected to the wellbore string to retrieve the first isolation device. In one or more embodiments, the shallow-positioned barrier system further includes a second delivery tool coupled to the second isolation device and the wellbore string, wherein the second delivery tool is disconnected from the wellbore string to position the second isolation device and reconnected to the wellbore string to retrieve the second isolation device. In one or more embodiments, the deep-positioned barrier system further includes one or more first anchors and one or more first protrusions of the one or more first anchors, wherein the one or more first protrusions extend to contact at least one of the wellbore, an annulus within the wellbore, and casing within the wellbore. In one or more embodiments, the shallow-positioned barrier system further includes one or more second anchors and one or more second protrusions of the one or more second anchors, wherein the one or more second protrusions extend to contact at least one of the wellbore, an annulus within the wellbore, and casing within the wellbore. In one or more embodiments, the deep-positioned barrier system further includes a first centralizer. In one or more embodiments, the shallow-positioned barrier system further includes a second centralizer. In one or more embodiments, the wellbore string includes a first wellbore string section connected to the first delivery tool and the shallow-set barrier system, and a second wellbore string section connected to the second delivery tool, wherein the first delivery tool disengages from the first wellbore string section to set the deep-set barrier system, and wherein the second delivery tool disengages from the second wellbore string section to set the shallow-set barrier system.

Claims

1. A method for setting up a single-pass delivery multi-barrier system, the method comprising: A single-injection multi-barrier system is deployed on a wellbore string in a formation wellbore, wherein the single-injection multi-barrier system includes a deep-set barrier system at the distal end of the wellbore string and a shallow-set barrier system above the deep-set barrier system. Determine whether the single-brace system has reached the first depth in the wellbore; Activate a mechanical locking system to unlock the first isolation device, the mechanical locking system including a spindle with circumferentially spaced lugs around the spindle, at least two lugs being longitudinally spaced along the spindle; The first isolation device of the deep-set barrier system is configured; Disconnect the deep-set barrier system from the wellbore tubing; The wellbore string is retrieved to a second depth within the wellbore. Apply annular pressure to unlock the second isolation device; The second isolation device of the shallow-set barrier system is provided, wherein the shallow-set barrier system includes a locking assembly comprising an actuating spindle, a fluid chamber, a rupture disc, and a lock, wherein the fluid chamber is sealed by one or more seals and the rupture disc, wherein air at atmospheric pressure initially fills the fluid chamber, and wherein the rupture disc is configured to rupture based on a predetermined hydrostatic pressure, allowing fluid outside the shallow-set barrier system to enter the fluid chamber through a port, thereby expanding the fluid chamber and causing the lock to move longitudinally relative to the actuating spindle; and Disconnect the shallow-set barrier system from the wellbore tubing; The first depth and the second depth are based on one or more parameters of the formation.

2. The method of claim 1, wherein setting the second device comprises: The explosion-proof sheet was ruptured; The lug is allowed to move within the continuous J-shaped slot; as well as It rises and pushes downwards on the wellbore string.

3. The method of any one or more of claims 1-2, wherein the first isolation device is coupled to the first delivery tool, and wherein disconnecting the deep-set barrier system from the wellbore string includes detaching the first delivery tool from the wellbore string.

4. The method of any one or more of claims 1-3, wherein the shallow-set barrier system is coupled to the second delivery tool, wherein the second delivery tool is coupled to the wellbore string, and wherein disconnecting the shallow-set barrier system from the wellbore string includes disengaging the second delivery tool from the wellbore string.

5. The method according to any one or more of claims 1-4, wherein the method further comprises: One or more first protrusions of one or more first anchors of the deep-set barrier system are extended to contact at least one of the wellbore, the annulus disposed within the wellbore, and the casing disposed within the wellbore.

6. The method according to any one or more of claims 1-5, wherein the method further comprises: One or more second protrusions of one or more second anchors of the shallow-set barrier system are extended to contact at least one of the wellbore, the annulus disposed within the wellbore, and the casing disposed within the wellbore.

7. The method of any one or more of claims 1-6, further comprising at least one of: maintaining the position of the first isolation device in the annulus of the wellbore via a first centralizer, maintaining the position of the second isolation device in the annulus of the wellbore via a second centralizer, and retrieving the wellbore string from the wellbore.

8. A single-pass multi-barrier system, the single-pass multi-barrier system comprising: A deep-set barrier system, wherein the deep-set barrier system includes a mechanical locking system, a first isolation device, and a first delivery tool, wherein the first delivery tool is connected to a first portion of a wellbore string, the mechanical locking system includes a mandrel with circumferentially spaced lugs around the mandrel, at least two lugs being longitudinally spaced along the mandrel, the deep-set barrier system being lowered to a first depth in the wellbore; A shallow-set barrier system, wherein the shallow-set barrier system includes a second isolation device and a second delivery tool, wherein the second delivery tool is coupled to a second portion of the wellbore string, and the shallow-set barrier system is lowered to a second depth in the wellbore; and The locking assembly of the shallow-set barrier system, wherein the locking assembly is locked and unlocked independently of the mechanical locking system of the deep-set barrier system, the locking assembly is configured to unlock by applying annular pressure, the locking assembly includes an actuating mandrel, a fluid chamber, a rupture disc, and a lock, wherein the fluid chamber is sealed by one or more seals and the rupture disc, wherein air at atmospheric pressure initially fills the fluid chamber, wherein the rupture disc is configured to rupture based on a predetermined hydrostatic pressure and allow fluid outside the shallow-set barrier system to enter the fluid chamber through a port, thereby expanding the fluid chamber and causing the lock to move longitudinally relative to the actuating mandrel; The first depth and the second depth are based on one or more parameters of the formation.

9. The single-feed multi-barrier system of claim 8, wherein the locking component includes a blast-proof plate that prevents the lug from moving within a series of J-shaped slots during the deployment of the first isolation device to prevent the deployment of the shallow-set barrier system.

10. The single-feed multi-barrier system of claim 9, wherein the lug moves within the continuous J-shaped slot to set the second isolation device when the blast-proof sheet breaks.

11. The single-pass multi-barrier system as described in claims 8-10, wherein the deep-set barrier system further comprises: At least one of the following: A first delivery tool is connected to the first isolation device and the wellbore string, wherein the first delivery tool is disconnected from the wellbore string to set the first isolation device and reconnected to the wellbore string to retrieve the first isolation device. as well as One or more first anchors and one or more first protrusions of the one or more first anchors, wherein the one or more first protrusions extend to contact at least one of the wellbore, an annulus disposed within the wellbore, and casing disposed within the wellbore.

12. The single-feed multi-barrier system as described in claims 8-11, wherein the shallow-set barrier system further comprises: At least one of the following: A second delivery tool is connected to the second isolation device and the wellbore string, wherein the second delivery tool is disconnected from the wellbore string to set up the second isolation device and reconnected to the wellbore string to retrieve the second isolation device; as well as One or more second anchors and one or more second protrusions of the one or more second anchors, wherein the one or more second protrusions extend to contact at least one of the wellbore, an annulus disposed within the wellbore, and casing disposed within the wellbore.

13. The single-feed multi-barrier system as described in claims 8-12, wherein at least one of the deep-set barrier systems further includes a first stabilizer and the shallow-set barrier system further includes a second stabilizer.

14. The single-entry multi-barrier system as described in claims 8-13, wherein the wellbore string includes a first wellbore string section connected to the first entry tool and the shallow-set barrier system, and a second wellbore string section connected to the second entry tool, wherein the first entry tool disengages from the first wellbore string section to set the deep-set barrier system, and wherein the second entry tool disengages from the second wellbore string section to set the shallow-set barrier system.

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