阅读说明：本技术 用于密封井眼的系统和方法 (System and method for sealing a wellbore ) 是由 维克托·卡洛斯·科斯塔德奥利韦拉 拉蒙·罗德里格斯·里科 哈立德·K·阿布埃勒纳吉 于 2018-04-11 设计创作，主要内容包括：描述了用于密封井眼的系统和方法。该系统包括：封隔元件,被配置为至少部分地进行密封以将井眼的上井部分与井眼的下井部分分隔；第一环空压力传感器位于封隔元件的上井处。第一环空压力传感器被配置为测量井眼内的封隔元件的上井处的第一压力。第二环空压力传感器位于封隔元件的下井处。第二环空压力传感器被配置为测量井眼内的封隔元件的下井处的第二压力。控制子组件被配置为位于井眼内。控制子组件被配置为通过比较第一压力和第二压力来监测系统的密封有效性。(Systems and methods for sealing a wellbore are described, the systems including a packing element configured to at least partially seal to separate an upper portion of the wellbore from a lower portion of the wellbore, an th annular pressure sensor located at the upper well of the packing element, a th annular pressure sensor configured to measure a th pressure at the upper well of the packing element within the wellbore, a second annular pressure sensor located at the lower well of the packing element, a second annular pressure sensor configured to measure a second pressure at the lower well of the packing element within the wellbore, a control subassembly configured to be located within the wellbore, and a control subassembly configured to monitor the sealing effectiveness of the system by comparing the th pressure and the second pressure.)

An wellbore monitoring system comprising:

a packing element configured to at least partially seal to separate an upper well portion of a wellbore from a lower well portion of the wellbore;

an th annulus pressure sensor located uphole of the packing element, the th annulus pressure sensor configured to measure a th pressure within the wellbore uphole of the packing element;

a second annulus pressure sensor located downhole of the packing element, the second annulus pressure sensor configured to measure a second pressure within the wellbore downhole of the packing element; and

a control sub-assembly configured to be positioned within the wellbore, the control sub-assembly configured to monitor a sealing effectiveness of the system by comparing the th pressure to the second pressure.

2. The system of claim 1, further comprising:

a cylindrical body supporting the packing element, the th annulus pressure sensor, the second annulus pressure sensor, and the control subassembly;

an th packer slip positioned closer to the upper downhole end of the cylindrical body than to the lower downhole end of the cylindrical body, the th packer slip configured to at least partially support the system, and

a second packer slip positioned closer to the lower downhole end of the cylindrical body than to the upper downhole end of the cylindrical body, the second packer slip configured to at least partially support the system.

3. The system of claim 2, wherein the packing element is located between the th packer slip and the second packer slip.

4. The system of claim 2, wherein the control subassembly comprises:

or more processors, and

a computer-readable medium storing instructions executable by the or more processors for performing operations comprising:

receiving instructions from a surface of the wellbore for performing a sealing operation within the wellbore; and

sending at least portions of the sealing instructions to the control subassembly, the sealing element at least partially sealing the wellbore in response to the sealing instructions.

5. The system of claim 4, wherein the operations further comprise:

receiving status signals from at least of the annulus pressure sensors indicative of a sealing status of the packing element, and

transmitting the status signal to the surface of the wellbore.

6. The system of claim 5, wherein the status signal comprises a status of the system, the status comprising an engaged status or a disengaged status, wherein an engaged status comprises the slip being in an extended position, the second slip being in an extended position, or the packing element being in an extended position, the extended position comprising a wall extending from the cylindrical body to the wellbore, and wherein a disengaged status comprises the packing slip, the second packing slip, and the packing element not extending from the cylindrical body to the wall of the wellbore.

7. The system of claim 6, further comprising:

or more transmitters at the surface of the wellbore, the or more transmitters configured to send the seal instructions to the or more processors, and

or more receivers at the surface of the wellbore, the or more receivers configured to receive the status signals from the or more processors.

8. The system of claim 7, wherein the or more transmitters and the or more receivers are configured to wirelessly communicate with the or more processors.

9. The system of claim 8, further comprising one or more repeaters, the one or more repeaters configured to be located between the earth surface and the control subassembly within the wellbore, the one or more repeaters configured to enhance the strength of wireless signals between the one or more transmitters or the one or more receivers and the one or more processors.

10. The system of claim 4, wherein the control subassembly further comprises a power source configured to be located within the wellbore, the power source operably coupled to the or more processors, the power source configured to provide operating power to the or more processors.

11. The system of claim 10, wherein the power source is an independent power source.

12. The system of claim 4, wherein the system further comprises a hydraulic power unit operatively coupled to the or more processors, the hydraulic unit configured to receive the at least portion of the commands from the or more processors.

13. The system of claim 12, wherein the hydraulic power unit comprises a hydraulic pump fluidly connected to the system, the hydraulic pump configured to supply hydraulic fluid at a pressure sufficient to activate the system.

14. The system of claim 13, wherein the hydraulic power unit is configured to actuate the -th packer slip, the second packer slip, or the packing element.

A method of sealing a wellbore of the type 15, , the method comprising:

receiving, by a control subassembly deployed within a wellbore, sealing instructions from a surface of the wellbore for performing a sealing operation within the wellbore;

sending, by the control assembly, at least portions of the sealing instructions to a packer subassembly, the packer subassembly comprising:

a cylindrical body;

a packer slip positioned closer to the upper downhole end of the cylindrical body than to the lower downhole end of the cylindrical body, the upper packer slip configured to at least partially support the packer subassembly;

a second packer slip positioned closer to the lower downhole end of the cylindrical body than to the upper downhole end of the cylindrical body, the second packer slip configured to at least partially support the packer subassembly;

a packing element positioned between the th packer slip and the second packer slip, the packing element configured to at least partially seal against a wellbore;

an th annulus pressure sensor located uphole of the packing element, the th annulus pressure sensor configured to measure a th pressure within the wellbore uphole of the packing element;

a second annulus pressure sensor located downhole of the packing element, the second annulus pressure sensor configured to measure a second pressure within the wellbore downhole of the packing element;

activating the packer subassembly to at least partially seal the wellbore; and

determining the effectiveness of the seal by comparing the th pressure to the second pressure.

16. The method of claim 15, further comprising:

sending, by the packer subassembly to the control assembly, a status signal indicative of a status of the packer subassembly; and

receiving, by the control assembly, the status signal from the packer subassembly.

17. The method of claim 16, further comprising sending, by the control assembly, the status signal from the packer subassembly to a surface of the wellbore.

18. The method of claim 15, wherein the packer subassembly further comprises a hydraulic unit comprising a hydraulic pump, wherein activating the th packer slip, the second packer slip, and the packing element by the packer subassembly to at least partially seal the wellbore comprises pumping hydraulic fluid by the hydraulic pump to mechanically activate the th packer slip, the second packer slip, or the packing element.

19, a method, comprising:

assembling to form a bottom hole assembly configured to be deployed in a wellbore to seal the wellbore:

a control assembly comprising one or more processors and a computer readable medium storing instructions executable by the one or more processors to seal the wellbore, and

a packer subassembly for sealing the wellbore;

deploying the bottom hole assembly in the wellbore; and

controlling the control assembly from the surface of the wellbore and using wireless signals to cause the packer subassembly to seal the wellbore.

20. The method of claim 19, further comprising:

receiving, by the control assembly, a status signal from the packer subassembly indicative of a status of a sealing operation; and

wirelessly transmitting, by the control assembly, the status signal to a surface of the wellbore.

21. The method of claim 20, wherein the status signal comprises a status of the packer subassembly, the status comprising an on or off state and a hydraulic pressure of the packer subassembly.

22. The method of claim 20, wherein the status signal comprises a pressure differential across the packer subassembly.

Technical Field

The present description relates to wellbore packers, for example, monitoring the sealing effectiveness of a wellbore packer.

Background

In order to seal the wellbore, the packer may be deployed to seal the wellbore with an elastomeric seal that extends radially outward from the cylindrical core to seal against the wall of the wellbore.

Disclosure of Invention

This specification describes technologies relating to sealing a wellbore. Techniques for monitoring the sealing effectiveness of a wellbore packer are also described.

The system includes a packing element configured to at least partially seal to separate an upper portion of a wellbore from a lower portion of the wellbore, a annulus pressure sensor located at the upper portion of the packing element, a annulus pressure sensor configured to measure a pressure at the upper portion of the packing element within the wellbore, a second annulus pressure sensor located at the lower portion of the packing element, a second annulus pressure sensor configured to measure a second pressure at the lower portion of the packing element within the wellbore.

The system may include, with or without any other aspect, a cylindrical body that supports a packing element, an th annular pressure sensor, a second annular pressure sensor, and a control subassembly, a th packer slip may be positioned closer to an upper uphole end of the cylindrical body than to the lower uphole end of the cylindrical body, a th packer slip may at least partially support the system.

The control assembly may include or more processors and computer readable media storing instructions executable by the or more processors to perform operations.

The operations, with or without any other aspect, may include receiving status signals from at least of the annulus pressure sensors indicative of a sealing status of the packing element, and sending the status signals to a surface of the wellbore.

The engaged state may include the slip in an extended position, the second slip in an extended position, or the packing element in an extended position, the extended position being from the cylindrical body to a wall of the wellbore.

The system may include or more transmitters at the surface of the wellbore, the or more transmitters may transmit seal instructions to or more processors, with or without any other aspects, the system may include or more receivers at the surface of the wellbore, the or more receivers may receive status signals from or more processors.

With or without any other aspects, or more transmitters and or more receivers may be configured to wirelessly communicate with or more processors.

With or without any other aspect, the system may include or more repeaters, the or more repeaters may be located between the control sub-assembly within the borehole and the earth's surface, and may enhance the strength of wireless signals between or more transmitters or or more receivers and or more processors.

With or without any other aspect, the control subassembly may include a power source, which may be located within the wellbore, may be operably coupled to or more processors, and may provide operating power to or more processors.

With or without any other aspect, the system may include a hydraulic power unit that may be operably coupled to or more processors and that may receive at least portions of the commands from or more processors.

The hydraulic power unit may include, with or without any other aspect, a hydraulic pump fluidly connected to the system and may supply hydraulic fluid at a pressure sufficient to activate the system.

The control assembly sends at least portions of the sealing instructions to a packer subassembly, the packer subassembly including a cylindrical body, a th packer slip positioned closer to an upper uphole end of the cylindrical body than the lower uphole end of the cylindrical body, a second packer slip positioned closer to a lower uphole end of the cylindrical body than the upper uphole end of the cylindrical body, a 387 packing element positioned between the 2 nd packer slip and the second packer slip, a th annular pressure sensor positioned at an uphole of the packing element, and a second annular pressure sensor positioned at a downhole of the packing element, each of the uphole packer slip and the second packer slip may at least partially support the subassembly, the packing element may at least partially seal the wellbore, the th annular pressure sensor and the second annular pressure sensor may be activated at least partially to measure the effectiveness of the sealing element at the downhole pressure of the packer subassembly, and the .

The packer subassembly may, with or without any other aspect, send a status signal to the control assembly indicative of the status of the packer subassembly. The control assembly may receive status signals from the packer subassembly.

The control assembly may send a status signal from the packer subassembly to the surface of the wellbore, with or without any other aspect.

To activate the th packer slip, the second packer slip, and the packing element to at least partially seal the wellbore, the hydraulic pump may pump hydraulic fluid to mechanically activate the th packer slip, the second packer slip, or the packing element.

The control assembly includes or more processors and computer readable media storing instructions executable by or more processors to seal the wellbore.

The control assembly may receive a status signal from the packer subassembly indicative of the status of the sealing operation, with or without any other aspect. The control assembly may wirelessly transmit the status signal to the surface of the wellbore.

The status signal may include the status of the packer subassembly, with or without any other aspect. The state may include an on state or an off state, and the hydraulic pressure of the packer subassembly.

The status signal may include a pressure differential across the packer subassembly, with or without any other aspect.

The details of or more embodiments of the subject matter described in this specification are set forth in the accompanying drawings and the description below.

Drawings

FIG. 1 is a side cross-sectional view of an example wellbore being sealed.

FIG. 2 is a side view of an example packer subassembly.

FIG. 3 shows a block diagram of an example control system.

Fig. 4A-4B show side cross-sectional views of an example packer slip.

Fig. 5A-5B show side cross-sectional views of example packing elements (engaged and disengaged).

FIG. 6 is a flow chart illustrating an example method of controlling a packer subassembly.

FIG. 7 is a flow chart illustrating an example method of utilizing a packer subassembly.

Like reference numbers and designations in the various drawings indicate like elements.

Detailed Description

Production and injection wellbores typically require sealing to perform maintenance or repair operations. Such repair and maintenance may include: replacing the damaged housing; replacing the damaged oil pipe; inspecting the well component; or any other necessary operation. During such operations, the wellbore may be sealed to allow safe access to the portion of the wellbore requiring attention. The seal may help prevent environmental release, fire, explosion, suffocation, and any other potential hazards resulting from hydrocarbon release.

Some operations require the seal to be in place and secured for a long period of time during which the seal integrity should be monitored to ensure that no oil and gas is released.

Packers may be used to provide the necessary seal during service and maintenance operations, but standard packers are difficult to set (set), and often require multiple attempts to provide a proper seal. Testing the seal between each attempt is cumbersome and time consuming. Packers are typically "dumb". That is, the packer cannot monitor its own seal integrity. Therefore, auxiliary equipment is often required to monitor the seal integrity of the packer.

The present specification discusses smart packers that may be included in a completion or test string, with the intent of mitigating such problems. The intelligent packer includes: a battery pack for powering the unit, a control unit for controlling the packer, a rubber packing element for sealing the drilling annulus (annuus), upper and lower pressure sensors to ensure the integrity/sealing of the rubber element, and upper and lower slip sets of slips for anchoring the packer to the wall of the wellbore. The intelligent packer is in wireless communication with the ground surface and is capable of transmitting data in real time. A smart packer can actuate (e.g., engage and disengage) its slips and rubber elements multiple times before retrieval is required. Smart packers eliminate risks such as premature setting or release, inability to manipulate or uncontrolled manipulation of the pipe, for example, due to differential pressure during circulation. The setting mechanism ensures that the proper setting force is transmitted to the packing element (also known as a packing rubber element or packer rubber element) to ensure zonal isolation and eliminate wireline operations. Smart packers may be used in vertical, horizontal, or deviated wellbores.

FIG. 1 shows an example cross-sectional view of a packer installation system 100. The packer installation system 100 may include a derrick 118 that may support a completion or test string 108 within a wellbore 106 that has been formed in a geological formation 104. While the illustrated embodiment shows the bottom hole assembly 102 deployed via the derrick 118 and string 108, a coiled tubing arrangement may also be used to deploy the bottom hole assembly 102. The bottom hole assembly 102 is located at the downhole end of the tubular string 108 and may include a control subassembly 101 and a packer subassembly 103. The control subassembly 101 may be mounted on and carried by the bottom hole assembly and may monitor the sealing effectiveness of the packer mounting system 100. The packer subassembly 103 will be described in more detail later in this description.

At the surface 116, the transmitter 113 and receiver 112 may be positioned in communication with the control subassembly 101 the packer installation system 100 may also include or more repeaters 114, which may be located between the surface 116 and the bottom hole assembly 102 within the wellbore 106. or more repeaters 114 may enhance the strength of the wireless signal between the control subassembly 101 and the surface 116.

FIG. 2 shows a schematic view of an example packer subassembly 103. in the example shown, the packer subassembly includes a cylindrical body having a th packer slip 212, the th packer slip 212 being closer to an upper (uphole) end 202 of the packer subassembly 103 than a lower (downhole) end 208 of the packer subassembly 103. the th packer slip 212 may at least partially support the packer subassembly 103 within the wellbore 106. the second packer slip 216 is positioned closer to the lower well end 208 of the packer subassembly 103 than to the lower well end 202 of the packer subassembly 103. the second packer slip 216 may at least partially support the packer subassembly 103 within the wellbore 106. although the illustrated embodiment includes the th and second packer slips 212, a different number (fewer or more) of slips may be used.

The annulus pressure sensor 206 is located uphole of the packing element 214 and measures the pressure within the wellbore 106 uphole of the packing element 214. the second annulus pressure sensor 218 is located downhole of the packing element 214 and measures the pressure in the wellbore downhole of the packing element 214. Each pressure sensor may be fixedly attached to the cylindrical body 220 of the packer subassembly 103. although the illustrated embodiment shows a single packing element and two pressure sensors, additional packing elements and sensors may be used.

The control subassembly 101 is located at the end of the packer subassembly 103 and may include a power source 210 and or more processors 204 FIG. 3 shows a detailed block diagram of the control subassembly 101. the control subassembly 101 may include 0 or more processors 204, and a computer readable medium 318 storing instructions that may be executed by the or more processors 204 to perform operations. or more processors 204 are also coupled to the th and second annulus pressure sensors 206, 218. or more processors may determine a pressure differential between the th and second annulus pressure sensors 206, 218. in some embodiments, more sensors may be used, and or more processors 204 may determine an absolute pressure of an additional sensor, or a relative pressure between the additional sensor and any other sensor.A control subassembly 101 may also include a transmitter 302 and a receiver 304. the transmitter 302 and receiver 304 may be used to receive sealing instructions from the surface of the wellbore, to perform operations within the packer subassembly 103, and may also transmit signals indicative of the status of at least the packer state 103, the packer status, or the packer status to send signals indicative of the packer status from the , the packer subassembly 103, or any other packer status signal receiver 106, the packer status, or any other signal indicating the packer status.

The control subassembly also includes a power source 210 that may be located within the wellbore, the power source 210 may be operably coupled to the one or more processors 204, and may provide operational power to or more processors 204. in some embodiments 0, the power source may be an independent power source located within the wellbore 106, such as a lithium ion battery (or other rechargeable power source). the packer installation system 100 may include or more hydraulic power units (e.g., . hydraulic power unit 310, second hydraulic power unit 312, or third hydraulic power unit 314) operably coupled to or more processors 204. any hydraulic power unit may receive at least a portion of a set of seal instructions from or more processors 204. in some embodiments, the hydraulic power units may be interconnected to allow the status of the hydraulic pumps to be changed ("on" or "off" commands), set a target pressure for the hydraulic pumps, or any other command that may be executed by the hydraulic power units may be interconnected to allow the hydraulic power units to communicate between each other hydraulic power unit, such as a hydraulic sensor , or other sensor may measure the hydraulic pressure sensor interconnection, or other hydraulic power unit may be interconnected to measure the pressure sensor communication pressure of the hydraulic power unit(s) and may be controlled by the hydraulic power unit .

4A-4B show side cross-sectional views of disengaged packer slips and engaged packer slips, respectively.the illustrated embodiment may be used for the th packer slips 212, the second packer slips 216, or any other packer slips. the packer subassembly 103 includes a hydraulic power unit 401 operatively coupled to the control subassembly 101. the hydraulic power unit 401 may be used as the aforementioned hydraulic power unit , such as the hydraulic power unit 310. the hydraulic power unit 401 may receive at least the portion of the seal command from the control subassembly 101. the portion of the seal command may include changing the state of the hydraulic pump, changing the output pressure of the hydraulic pump, changing the position of an actuatable (active-able) tool having an actuation capability, or any other command that may be executed by the hydraulic power unit. th packer 212 may be operatively coupled to the hydraulic power unit 401, that is, in response to being actuated by the control subassembly 101, the hydraulic power unit 401 may mechanically actuate the packer subassembly 103 to initiate a sealing operation within the packer 106. for example, the hydraulic power unit 401 may itself include a slip fluidly connected to the packer 212 to extend the hydraulic power unit 103 to at least the hydraulic pressure subassembly 103 and to store hydraulic fluid information in the packer subassembly 103, such as the hydraulic pressure sensor 103, and to actuate the hydraulic power unit 103 to extend the packer subassembly 103 to at least the packer subassembly 103 and to initiate the packer subassembly 103, and to initiate the hydraulic pressure sensor 103 may include a hydraulic pressure sensor to initiate the packer subassembly 103 to initiate the packer subassembly 3 to initiate the packer subassembly 103.

When the hydraulic power unit 401 has received a signal to activate the packer subassembly 103, the hydraulic pump 404 moves hydraulic fluid from the full hydraulic reservoir 402a to the unexpanded swell member 406 a. the unexpanded swell member 406a begins to expand and becomes the expanded swell member 406 b. similarly, during activation of the packer subassembly 103, the full hydraulic reservoir 402a becomes the depleted (depleded) hydraulic reservoir 402 b. that is, activating at least packer slips (e.g., the first packer slip 212) includes pumping hydraulic fluid with the hydraulic pump 404 to mechanically activate the respective packer slips. the expanded swell member 406b moves the wedge mandrel 408 toward the second slip 212. the wedge mandrel 408 extends the packer's fifth packer slip 212 radially outward from the packer subassembly 103 and toward the wall of the wellbore 106. when the sealing operation is complete, the control subassembly 101 may send a signal to the hydraulic pump 404 to pump hydraulic fluid from the expanded swell member 406b back into the depleted packer subassembly 402b, the packer subassembly 103 b may include a retracting device (e.g., a spring to retract the hydraulic power unit 406b to retract the hydraulic fluid from the expanded hydraulic power unit 406b to connect the packer subassembly 103 in a single hydraulic power unit 3875, to control the hydraulic fluid connection of the packer subassembly 401, which may be removed in a single hydraulic power unit 401, and a hydraulic fluid connection of the packer subassembly 3, which may be removed in a single hydraulic power unit 3.

5A-5B illustrate example cross-sectional views of an example packing element 214 at various stages of operation, in FIG. 5A, the packing element 214 is in a disengaged mode, and in FIG. 5B, the packing element 214 is in an engaged mode, the packing element 214 includes a hydraulic power unit 501 operatively coupled to the control subassembly 101, the hydraulic power unit 501 may function as the aforementioned hydraulic power unit (e.g., the second hydraulic power unit 312), the hydraulic power unit 501 may receive at least a portion of a seal command from the control subassembly 101, the portion of the seal command may include changing a state of the hydraulic pump, changing an output pressure of the hydraulic pump, changing a position of an actuatable (active-able) tool, or any other command that may be executed by the hydraulic power unit, the scraping tool may be operatively coupled to the hydraulic power unit 501, that is, the hydraulic power unit 501 may mechanically actuate the packing element 214 to begin a sealing operation within the wellbore 106 in response to being mechanically actuated by the hydraulic power unit 501, the hydraulic power unit 501 may extend the packing element 214 radially outward toward the wellbore 106, for example.

When the hydraulic power unit 501 has received a signal to activate the packing element 214, the hydraulic pump 504 moves hydraulic fluid from the full hydraulic reservoir 502a to the unexpanded expansion member 506 a. the unexpanded expansion member 506a begins to expand and becomes the expanded expansion member 506 b. similarly, during activation of the packing element 214, the full hydraulic reservoir 502a becomes the depleted hydraulic reservoir 502 b. the expanded expansion member 506b moves the wedge mandrel 508 toward the packing element 214. the wedge mandrel 408 extends the packing element 214 radially outward from the packer subassembly 103 and toward the wall of the wellbore 106. in embodiments, the mandrel need not be wedge-shaped; alternatively, the mandrel may be flat and the packing element may be radially expanded by laterally compressing the packing element. when the sealing operation is complete, the control subassembly 101 may send a signal to the hydraulic pump to pump hydraulic fluid from the expanded expansion member 506b back into the depleted hydraulic fluid reservoir 502 b. the packing element 214 may include a retraction device (e.g., a spring) to act as a single hydraulic fluid connection to the packer subassembly 506b to retract the hydraulic power unit 501 in a single hydraulic power unit 3942 connection mode, a single hydraulic power unit 501 may retract under , a single hydraulic fluid connection sub-3632, a hydraulic power unit 501 may be retracted under a single hydraulic power unit 501, a single embodiment, a single hydraulic fluid connection sub , a hydraulic fluid connection to control unit, a packer, and a packer assembly.

FIG. 6 illustrates a flow chart of an example method 600 for controlling the packer subassembly 103. at 602, a sealing command for performing a sealing operation within the wellbore 106 is received by the control subassembly 101 deployed within the wellbore 106 from the surface 116 of the wellbore 106. at 604, at least portions of the sealing command are sent by the control subassembly 101 to the packer subassembly 103. at 606, the packer subassembly 103 is activated to at least partially seal the wellbore 106. at 608, the effectiveness of the seal is determined by comparing the th pressure to the second pressure. if the seal is not successful, the packer subassembly may additionally actuate the packing element 214 at least times to retry a successful seal.

FIG. 7 shows a flow diagram of an example method 700 for utilizing the packer subassembly 103, at 702, components that can be deployed in a wellbore are assembled to form a bottom hole assembly 102 for sealing the wellbore 106, the components can include a control subassembly 101 and the packer subassembly 103 for sealing the wellbore 106, the control subassembly 101 having or more processors 204, and a computer readable medium 318 storing instructions that can be executed by or more processors 204 to seal the wellbore 106, at 704, the bottom hole assembly 102 is deployed in the wellbore 106, at 706, the control subassembly 101 is controlled from the surface 116 of the wellbore 106 using wireless signals to engage the packer subassembly 103 to seal the wellbore 106, a status signal is received by the control subassembly 101 from the packer subassembly 103 that represents a status of a sealing operation, a status signal is wirelessly sent by the control subassembly 101 to the surface 116 of the wellbore 106, the status signal can include a status of the packer subassembly 103 (e.g., an "on" status or an "off" status), a hydraulic pressure of the packer subassembly, a differential pressure across the packer subassembly, or any other status.

Specific embodiments of the present subject matter have been described. Other embodiments are within the scope of the following claims.