CROSS-REFERENCE TO RELATED APPLICATION

[0001] This application claims priority to U.S. Non-Provisional Patent Application No. 17/589,954 filed on February 1, 2022, which is incorporated herein in its entirety.

BACKGROUND

[0002] Multilateral wells may be formed by performing a sidetracking operation to form a secondary wellbore from a primary wellbore. In conventional systems, sidetracking operations require milling assemblies to cut a window into a casing of the primary wellbore. Milling assemblies require significant time to operate and are therefore costly. Further, the use of milling assemblies requires human intervention during milling and therefore is prone to human error.

[0003] Accordingly, a need exists for alternative systems and methods for sidetracking operations that are time-effective and rely less on human intervention.

BRIEF SUMMARY

[0004] According to the subject matter of the present disclosure, a bottomhole assembly is described for performing a sidetracking operation in a casing of a wellbore. The assembly includes a body, a fluid intensifier, a fluid jetting nozzle, a side arm, and a hook. The fluid intensifier is configured to receive fluid and configured to increase a pressure of the fluid. The fluid jetting nozzle is associated with the body. The fluid jetting nozzle is fluidly coupled to the fluid intensifier and is configured to receive pressurized fluid from the fluid intensifier. The fluid jetting nozzle is configured to cut a window into the casing via the pressurized fluid. The side arm is movable between a closed position wherein the side arm is retracted and a guiding position wherein the side arm is extended. The side arm is configured to contact the casing in the guiding position to guide the body within the casing. The hook disposed on the body and configured to couple to the cut window and remove the cut window from the casing.

[0005] In accordance with another embodiment of the present disclosure, a method is described for performing a sidetracking operation in a casing of a wellbore. The method includes guiding a body of a bottomhole assembly within the casing via a side arm extending from the body in contact with the casing. The method further includes descending the body to a cutting depth, the cutting depth being a predetermined depth within the casing for performing the sidetracking operation. The method further includes operatively driving a fluid intensifier of the bottomhole assembly to a power supply of the bottomhole assembly. The method further includes increasing a pressure of a fluid in the fluid intensifier. The method further includes cutting a window into the casing via a fluid jetting nozzle associated with the body, the fluid jetting nozzle being fluidly coupled to the fluid intensifier and configured to receive pressurized fluid from the fluid intensifier. The method further includes coupling a hook disposed on the body into the cut window and removing the cut window from the casing.

[0006] In accordance with another embodiment of the present disclosure, a bottomhole assembly is described for performing a sidetracking operation in a casing of a wellbore. The assembly includes a body, a fluid intensifier, a fluid jetting nozzle associated with the body, a side arm, a hook disposed on the body, and a telemetry system. The fluid intensifier is configured to receive fluid and is configured to increase a pressure of the fluid. The fluid jetting nozzle is fluidly coupled to the fluid intensifier and is configured to receive pressurized fluid from the fluid intensifier. The side arm is movable between a closed position where the side arm is retracted and a guiding position where the side arm is extended. The side arm is configured to contact the casing in the guiding position to guide the body within the casing. The telemetry system is communicatively coupled to the body, to the fluid intensifier, to the fluid jetting nozzle, and to the side arm. The telemetry system is configured to communicate with the body to descend the body to a cutting depth, the cutting depth being a predetermined depth within the casing for performing the sidetracking operation. The telemetry system is further configured to communicate with the fluid jetting nozzle to cut a window into the casing via the pressurized fluid. The telemetry system is further configured to communicate with the hook to couple to the cut window and remove the cut window from the casing.

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

[0007] The following detailed description of specific embodiments of the present disclosure can be best understood when read in conjunction with the following drawings, where like structure is indicated with like reference numerals and in which:

[0008] FIG 1 illustrates a bottomhole assembly (BHA) within a casing of a wellbore, according to some embodiments; [0009] FIG 2 illustrates a guiding profile that may be removably coupled to the BHA of FIG. 1, according to some embodiments;

[0010] FIG. 3 illustrates the BHA of FIG. 1 in a sidetracking operation, according to some embodiments;

[0011] FIG. 4 illustrates the BHA of FIG. 1 continuing in the sidetracking operation, according to some embodiments;

[0012] FIG. 5 illustrates BHA of FIG. 1 continuing in the sidetracking operation, according to some embodiments; and

[0013] FIG. 6 illustrates an example sidetracking operation method, according to some embodiments.

DETAILED DESCRIPTION

[0014] Sidetracking is the operation of drilling a secondary wellbore from an original wellbore. Sidetracking allows for the bypassing of sections of the original wellbore that are unable to be used. Sidetracking is also used to explore geologic resources proximate to the original wellbore. To begin the sidetracking operation, a window must be removed from a casing within the original wellbore to provide access for a drill. The location of the window is the point in which the secondary wellbore deviates from the original wellbore.

[0015] Referring initially to FIG. 1, a system 100 for performing a sidetracking operation is shown according to the some embodiments. The system 100 includes a wellbore 102. The wellbore 102 is a drilled hole, or borehole, extending from the surface used to aid in the exploration and recovery of oil and gas. The wellbore 102 may include a casing 104 which extends through the wellbore 102. The casing 104 isolates equipment used to recover recourses and the recovered resources within the casing 104 from an exterior of the casing 104. The casing is configured to withstand a variety of external forces caused from collapsing, bursting, tensile failure, and the like. The casing 104 may be constructed of steel, stainless steel, aluminum, titanium, fiberglass, or other materials of the like. An exterior wall of the casing 104 may be enclosed (e.g., surrounded) with cement in order to fix the casing 104 in place within the wellbore 102. [0016] The system 100 may include a botomhole assembly (BHA) 106. The BHA 106 may be positioned on a lower portion of a drillstring (not shown) and may be positioned within the casing 104. The BHA 106 may provide directional drilling within the casing 104 by providing a large force onto a drilling bit (not shown). The BHA 106 is configured to withstand a harsh drilling environment within the casing 104 and may be further configured to facilitate communication with the surface. As discussed in greater detail herein, the BHA 106 includes several components which enable the sidetracking operation to be performed. In system 100, the BHA 106 may be configured to cut a window into the casing 104 and then retrieving that window before performing the sidetracking operation. A center axis of the BHA 106 defines a longitudinal axis a along a length of the BHA 106.

[0017] The system 100 may include a drill pipe 108 positioned on an upper portion of the BHA 106. The drill pipe 108 extends from the upper portion of the BHA 106 to a portion of the drillstring. Accordingly, the drill pipe 108 mechanically couples (e.g., integrates, connects) the drillstring to the BHA 106. The BHA 106 further includes a body 109 coupled to the drill pipe 108. The body 109 extends from the drill pipe 108 to a bottom surface of the BHA 106. The body 109 may be centered on the longitudinal axis a. As discussed in greater detail herein, components of the BHA 106 may be positioned within the body 109.

[0018] The BHA 106 may include a controller 110 (e.g., processor, computing unit). The controller 110 may be configured to load executable programs for the BHA 106 and to execute the executable programs. As discussed in greater detail herein, the BHA 106 may be communicatively coupled to the various components of the BHA 106 and may be configured to control the operation of these various components.

[0019] The controller 110 may include a telemetry system 110a (e.g., communication system) positioned within the BHA 106. The telemetry system 110a facilitates for communication between the controller 110 and the surface. In this way, the telemetry system 110a provides communication between the BHA 106 and the operators of the system 100. The telemetry system 110a may be configured to generate and/or receive signals in the form of pressure pulses within a fluid medium. Further, the controller 110 may provide information (e.g., sensor readings, report issues) to the operators. This may be advantageous as the operation of the BHA 106 may be controlled and monitored by the operators. The fluid medium in which the pressure pulses are emitted within may be referred to as mud. The mud may consist of drilling fluid (e.g., cuting fluid), suspended solids, emulsified water, or oil which surrounds the BHA 106 and the drillstring. Other approaches for communicating the controller 110 to the surface may also be utilized.

[0020] The BHA 106 may further include a side arm 111 movable between a closed position and a guiding position. The side arm 111 may be translated by a motor (not shown) within the BHA 106. In the closed position, the side arm 111 may be at least partially retracted within the body 109 or may be adjacent to the body 109 (e.g., extends parallel to the body 109). This may be advantageous as it mitigates damage to the side arm 111 during the translation of the BHA 106 within the wellbore 102. In the guiding position, the side arm 111 extends away from the body 109 and extends towards the casing 104. In the guiding position, the side arm 111 guides the BHA 106 within the casing 104 by translating away from the casing 104 by a distance D. Based on an angle 0 of the side arm 111 relative to the longitudinal axis a, the BHA 106 may determine the distance D away from a wall of the casing 104. In some embodiments, in the guiding position, the side arm 111 may be translated 5° to 10° relative to the longitudinal axis a. In some embodiments, in the guiding position, the side arm 111 may be translated 10° to 25° relative to the longitudinal axis a. In some embodiments, in the guiding position, the side arm 111 may be translated 25° to 60° relative to the longitudinal axis a.

[0021] The side arm 111 may be communicatively coupled to the controller 110. The controller 110 may receive a signal from the surface to move the BHA 106 a specified distance away from the casing 104. The controller 110 may then provide a signal to the side arm to translate a specified angle that may be mapped to (e.g., related to, determined to be equal to) the specified distance away from the casing 104.

[0022] In some embodiments, the BHA 106 includes a plurality of side arms. For example, and as shown in FIG. 3, the BHA 106 may include a second side arm 11 la that co-operates with the side arm 111 to guide the BHA 106 within the casing 104. The plurality of side arms are communicatively coupled to the controller 110 in order to provide additional references points to guide the BHA 106 within the casing 104.

[0023] Referring again to FIG. 1, the BHA 106 may further include an abrasive material supply 112 positioned within the lower portion of the BHA 106. The abrasive material in the abrasive material supply 112 may be constructed of a mineral such a garnet, staurolite, sand, or any other suitable abrasive. In embodiments, the abrasive material supply 112 may be positioned within the upper portion of the BHA 106. In embodiments, the abrasive material supply 112 may be positioned within the drillstring.

[0024] The system 100 may further include a fluid supply (not shown). The fluid supply extends along a length of the drillstring and along a portion of the BHA 106. The fluid supply provides fluid (e.g., water, cutting fluid) from the surface to the BHA 106.

[0025] The BHA 106 may further include a fluid intensifier 114 positioned within the lower portion of the BHA 106. The fluid intensifier 114 may be in fluid communication with the fluid supply. The fluid intensifier 114 greatly increases a pressure of the received fluid through an intensifier pump. In embodiments, the fluid intensifier 114 increases the pressure of the fluid to be between 30,000 to 40,000 PSI. In embodiments, the fluid intensifier 114 increases the pressure of the fluid to be between 40,000 to 60,000 PSI. In embodiments, the fluid intensifier 114 increases the pressure of the fluid to be between 60,000 to 100,000 PSI. In embodiments, the fluid intensifier 114 may be positioned within the upper portion of the BHA 106. In embodiments, the fluid intensifier 114 is positioned within the drillstring. The controller 110 may be communicatively coupled to the fluid intensifier 114 and thereby controls the operation of the fluid intensifier 114 (e.g., activation of the fluid intensifier, the desired pressure range of the fluid).

[0026] The BHA 106 may further include a power supply 115 (e.g., battery, power source) positioned within the BHA 106. The power supply 115 may be operatively coupled to the fluid intensifier 114, thereby providing power to the fluid intensifier 114 in order for the fluid intensifier 114 to operate. The controller 110 may be communicatively coupled to the power supply 115 and thereby controls the operation of the power supply 115 (e.g., activation of the fluid intensifier, the desired pressure range of the fluid).

[0027] The BHA 106 may further include a mixing chamber 116 which may be positioned within the lower portion of the BHA 106. The mixing chamber 116 may be fluidly coupled to the abrasive material supply 112 and the fluid intensifier 114. The mixing chamber 116 receives abrasive material from the abrasive material supply 112 and the pressurized fluid from the fluid intensifier 114 and mixes the abrasive material with the pressurized fluid to form an abrasive pressurized fluid. In embodiments, the mixing chamber 116 may be positioned within the upper portion of the BHA 106. In embodiments, the mixing chamber 116 may be positioned within the drillstring. The controller 110 may be communicatively coupled to the mixing chamber 116 and thereby controls the operation of the mixing chamber 116 (e.g., activation of the mixing chamber 116, the desired mixing ratio of the abrasive material relative to the fluid volume).

[0028] By using the fluid intensifier 114 with the abrasive material supply 112, the BHA 106 may be capable of producing an abrasive pressurized fluid capable of cutting into the casing 104. This is advantageous as special pump equipment capable of handling a harsh environment is not required. Further, by using the fluid intensifier 114 within the BHA 106, there is not a need for pumps to be placed on the surface which transmit pressurized fluid along the entire length of the drillstring. This is advantageous as it increases the safety and operational efficiency of the cutting operation.

[0029] The BHA 106 may further include a fluid jetting nozzle 118 which may be positioned within the lower portion of the BHA 106. The fluid jetting nozzle 118 may be movable between a retracted position and a cutting position. In the retracted position, the fluid jetting nozzle 118 may be positioned within the body 109 of the BHA 106. In the cutting position, the fluid jetting nozzle 118 extends away from the body 109 of the BHA 106. The fluid jetting nozzle 118 may be fluidly coupled to the mixing chamber 116 and may be configured to receive abrasive pressurized fluid from the mixing chamber 116. In embodiments, the fluid jetting nozzle 118 receives pressurized fluid directly from the fluid intensifier 114. The fluid jetting nozzle 118 directs the flow of the received abrasive pressurized fluid to the casing 104, thereby cutting a window 104a into the casing 104. In embodiments, the fluid jetting nozzle 118 directs the fluid generally orthogonal to the longitudinal axis a. However, the fluid jetting nozzle 118 may be movable to dispense fluid ± 45° relative to an axis orthogonal to the longitudinal axis a. In embodiments, the fluid jetting nozzle 118 may be positioned within the upper portion of the BHA 106. The controller 110 may be communicatively coupled to the fluid jetting nozzle 118 and thereby controls the operation of the fluid jetting nozzle 118 (e.g., activation of the fluid jetting nozzle 118, the desired direction of the fluid stream dispensed by the fluid jetting nozzle 118).

[0030] The BHA 106 may further include hooks 122 positioned on a mid-portion of the BHA 106. The hooks 122 are movable between a retracted position and a retrieving position. In the retracted position, the hooks 122 are at least partially positioned within the body 109. This is advantageous as it mitigates damage to the hooks 122 during the translation of the BHA 106 within the wellbore 102. In the retrieving position, the hooks 122 extend away from the body 109 and towards the casing 104. After the window 104a has been cut by the fluid jetting nozzle 118, the hooks 122 couple to the cut window 104a. In embodiments, after coupling to the window 104a, the hooks 122 move away from the casing 104, thereby removing the window 104a from the casing 104. In embodiments, after coupling to the window 104a, the BHA 106 translates away from the casing 104, thereby removing the window 104a from the casing 104. The controller 110 may be communicatively coupled to the hooks 122 and thereby controls the operation of the hooks 122 (e.g., moving the hooks 122 between the retracted position and the retrieving position, activating the hooks 122 to couple to the window).

[0031] In embodiments, the hooks 122 are a plurality of drills which couple to the window 104a by drilling into the window 104a. In some embodiments, the hooks 122 are clamps, latches, or the like which couple to the window 104a.

[0032] The BHA 106 may further include a drilling jar 120 which may positioned on an upper portion of the BHA 106. The drilling jar 120 may be a mechanism in which generates an impact force. In embodiments, the impact force may be directed to a path orthogonal to the longitudinal axis a. In embodiments, the impact force may be directed to a path along the longitudinal axis a. In embodiments, the impact force may be generated by a mechanical mechanism or by a hydraulic mechanism. The drilling jar is configured to have restricted range of motion within the BHA 106. During the retrieval operation of the window 104a by the hooks 122, the drilling jar 120 applies the impact force upon the hooks 122 in order to break down the cement behind the casing 104. In this way, an opening for a secondary wellbore may be formed from the wellbore 102. In embodiments, the drilling jar 120 may be positioned within the lower portion of the BHA 106. The controller 110 may be communicatively coupled to the drilling jar 120 and thereby controls the operation of the drilling jar 120 (e.g., activation of the drilling jar 120, direction of the impact force by the drilling jar 120).

[0033] Referring now to FIG. 2, a guiding system 200 is shown, according to some embodiments. As discussed in greater detail herein, in some embodiments the guiding system 200 may be used in conjunction with the system 100 during the sidetracking operation. The guiding system 200 may include a primary latching mechanism 202 on a top surface of the guiding system 200. The primary latching mechanism 202 may be removably coupled to a bottom surface of the BHA 106. As discussed in greater detail herein, when the BHA 106 is coupled to the guiding system 200, the BHA controls the translation of the guiding system 200 within the casing 104.

[0034] The guiding system 200 may further include mounting latches 204 positioned on a bottom surface of the guiding system 200. As discussed in greater detail herein, the mounting latches 204 facilitate for the guiding system 200 to mount onto the casing 104. The mounting latches 204 are retractable into a body of the guiding system 200 in order to mitigate damage to the mounting latches 204 during translation of the guiding system 200.

[0035] The guiding system 200 may further include inflatable packers 206. After the mounting latches 204 mount onto the casing 104, the inflatable packers 206 are inflated. The inflatable packers 206 isolate a bottom portion of the wellbore 102 beneath the guiding system 200 from a top portion of the wellbore 102 above the guiding system 200 by creating a 360° seal. This is advantageous as it prevents pressure differences between the bottom portion of the wellbore 102 and the top portion of the wellbore 102 from disrupting the cutting operation. Further, it prevents shavings from the cutting operation from falling into the bottom portion of the wellbore 102 as the shavings are caught by the guiding system 200.

[0036] The guiding system 200 may further include a guiding profile 208. The guiding profile 208 may be a cable (e.g., wire, net) extending from a first wall 205a of the guiding system 200 to a second wall 205b of the guiding system 200. As discussed in greater detail herein, the guiding profile 208 guides the BHA 106 to a correct cutting depth before the cutting operation. The guiding profile 208 may be constructed of a flexible material (e.g., rubber). This is advantageous as it allows for the BHA 106 to make contact with the guiding profile 208 without damaging the BHA 106.

[0037] After the cutting operation of the BHA 106 is conducted, the guiding system 200 may be removed from the wellbore 102. The guiding system 200 may be coupled to a retrieving tool via the primary latching mechanism 202. During retrieval the force of removing the guiding system 200 deflates the inflatable packers 206. In some situations, the retrieving tool may not properly couple to the primary latching mechanism 202 (e.g., due to not making a proper clamping mechanism, cannot accurately find the primary latching mechanism 202). To ensure retrieval, the guiding system 200 may further include a secondary latching mechanism 210 positioned on the first wall 205a of the guiding system 200. In this way, the retrieval device has a secondary location to latch onto the guiding system 200 for retrieval. [0038] In scenarios where the secondary latching mechanism 210 is difficult to latch onto, the guiding system 200 may further include a tertiary latching mechanism 212 positioned on the second wall 205b. In these scenarios, the retrieval tool latches onto both the secondary latching mechanism 210 and the tertiary latching mechanism 212. This results in an equal force to be applied onto the guiding system 200 enough to deflate the inflatable packers 206 and remove the guiding system 200 from the wellbore 102.

[0039] Now referring to FIG. 3, the BHA 106 and the guiding system 200 are shown during a sidetracking operation 300, according to some embodiments. The sidetracking operation 300 begins with the guiding system 200 being removably coupled to the BHA 106 via the primary latching mechanism 202. The side arm 111 and the side arm 11 la are used to guide a position of the BHA 106 and the guiding system 200 within the casing 104. The side arm 111 and the side arm I l la extend away from the body 109 by a specified angle. This results in the BHA 106 and the guiding system 200 to be separated away from a point of the circumference of the casing 104 by a specified distance. In this way, the BHA 106 is at a specified location within the casing 104. The desired position of the BHA 106 within the casing 104 may be communicated to the controller 110 via the telemetry system 110a from the surface. During the guiding process, the hooks 122 are in the retracted state in the body 109.

[0040] Through the telemetry system 110a, the controller 110 provides the depth of the BHA 106 to the surface. Accordingly, the telemetry system 110a communicates when the BHA 106 reaches a cutting depth CD. The cutting depth CD is a depth measured along a center axis of the wellbore 102 from the surface. In embodiments, the cutting depth CD may be pre-programmed so that the BHA 106 is configured to translate automatically until it reaches the cutting depth CD.

[0041] When the cutting depth CD is reached, the mounting latches 204 are activated, thereby coupling the guiding system 200 to the casing 104. In embodiments, the controller 110 of the BHA 106 may be communicatively coupled to the guiding system 200, thereby instructing the mounting latches 204 to be activated. In embodiments, the guiding system 200 includes a respective controller and telemetry system that are configured to communicate with the BHA 106 and the surface.

[0042] Once the guiding system 200 is coupled to the casing, the inflatable packers 206 are inflated. When the inflatable packers 206 are inflated, the bottom portion of the wellbore 102 is isolated from the top portion of the wellbore 102. This prevents pressure differences between the portions from effecting the cutting operation, diluting pressure pulses from the surface from being received by the telemetry system 110a, and preventing shavings from the cutting operation from dropping into the bottom portion of the wellbore 102. Further, the guiding system 200 may be used after the sidetracking operation 300 to maintain isolation between the bottom portion of the wellbore 102 and the top portion of the wellbore 102 to avoid pressure differences disrupting the drilling of the secondary wellbore.

[0043] At this point, the side arms 111 return to the closed position and the BHA 106 performs a slack-off test. The slack-off test consists of the BHA 106 applying a pressure onto the guiding system 200 to ensure the inflatable packers 206 are properly set onto the casing 104. If the inflatable packers 206 are properly set, the BHA 106 will removably couple from the guiding system 200.

[0044] Referring now to FIG. 4, the sidetracking operation 300 continues with the side arms 111 being returned to the guiding position and separating the BHA 106 away from the guiding system 200. The side arms 111 then guide the BHA 106 to a cutting position. The cutting position is a location within the casing 104 proximate to the cutting depth CD. Once the BHA 106 is at the cutting position, the cutting operation now commences. During the cutting operation, the guiding profile 208 prevents damage to the BHA 106 in case of collision between the guiding system 200 and the BHA 106.

[0045] During the cutting operation, the power supply 115 provides power to the fluid intensifier 114. The fluid intensifier 114 begins increasing the pressure of the received fluid from the fluid supply. The pressurized fluid may be provided to the mixing chamber 116. Additionally, the abrasive material supply 112 provides abrasive material to the mixing chamber 116. The mixing chamber 116 mixes the pressurized fluid with abrasive material to form a pressurized abrasive fluid. The pressurized abrasive fluid may be then provided to the fluid jetting nozzle 118.

[0046] The fluid jetting nozzle 118 begins to cut the window 104a into the casing 104. In conventional systems, a cutting profile is defined during the cutting operation. This may lead to human error and in an untimely process. In certain embodiments, the cutting profile of the window 104a is pre-programmed prior to the cutting operation. In this way, the cutting operation is timely and not prone to human error. While cutting, the BHA 106 may rotate in order to dispense heat created during the cutting process. In this way, the BHA 106 may remain cool during the cutting process.

[0047] Referring now to FIG. 5, the sidetracking operation 300 is shown during the retrieval process. During the retrieval process, the fluid jetting nozzle 118 returns to its retracted position. Further, the hooks 122 move to the retrieving position in which the hooks 122 extend away from the body 109. In embodiments where the hooks 122 are a plurality of drills, the hooks 122 drill into the window 104a. While removing the window 104a from the casing 104, the drilling jar 120 applies an impact force onto the hook 122, thereby applying the impact force onto the cement surrounding the casing 104. This is in order to break the cement behind the window 104a. In this way, an opening is formed for the secondary wellbore. With the window 104a removed from the casing, the BHA 106 returns to the surface with the window 104a being coupled to the hooks 122. In embodiments, the drilling jar 120 applies the impact force onto the cement surrounding the casing 104 after removing the window 104a from the casing 104.

[0048] While returning to the surface the side arms 111 are still in the guiding position in order to guide the BHA 106. After lateral drilling of the secondary wellbore is completed, the guiding system 200 may also be removed by using either the primary latching mechanism 202, the secondary latching mechanism 210 and/or the tertiary latching mechanism 212.

[0049] Referring now to FIG. 6, a method 600 for performing a sidetracking operation is shown. The method 600 may be performed by a BHA (e.g., such as BHA 106) in a wellbore (e.g., such as wellbore 102). The steps of method 600 may be performed by a controller (e.g., such as controller 110) positioned within the BHA. The controller may be configured to communicate with the surface and with various components of the BHA via a telemetry system (e.g., such as telemetry system 110a).

[0050] At step 602, a body of the BHA (e.g., such as body 109) may be guided within a casing (e.g., such as casing 104) of the wellbore. The body may be guided by side arms (e.g., such as side arm 111 and side arm I l la) which place the body in a determined position within the casing. The position of the body may be controlled by a controller (e.g., such as controller 110) positioned with the BHA. The controller communicates with the surface via a telemetry system (e.g., such as telemetry system 110a). [0051] At step 604, the body descends to a cutting depth (e.g., such as cutting depth CD). In some embodiments, the body may be coupled to a guiding system (e.g., such as guiding system 200). At the cutting depth, the guiding system may be coupled to the casing and removably detached from the body. Additionally, the guiding system may inflate inflatable packers (e.g., such as inflatable packers 206), in order to isolate a lower portion of the wellbore from a top portion of the wellbore.

[0052] At step 606, power from a power supply (e.g., such as power supply 115) may be provided to a fluid intensifier (e.g., such as fluid intensifier 114) of the BHA. At step 608, a pressure of a fluid received in the BHA may be then increased by the fluid intensifier. The pressurized fluid may be mixed with abrasive material supplied by an abrasive material supply (e.g. such as abrasive material supply 112) in a mixing chamber (e.g., such as mixing chamber 116).

[0053] At step 610, a fluid jetting nozzle (e.g., such as fluid jetting nozzle 118) of the BHA receives pressurized abrasive fluid from the mixing chamber. The fluid jetting nozzle then cuts a window into the casing with the pressurized abrasive fluid. The cutting path of the fluid jetting nozzle may be preprogrammed prior to the cutting operation. This is advantageous as it reduces the time of the cutting process and reduces human error.

[0054] At step 612, a hook (e.g., such as hooks 122) of the BHA may be coupled into the window. At step 614, the cut window may be then removed from the casing. During the removal of the cut window, a drilling jar (e.g., such as drilling jar 120) applies an impact force onto the hook thereby applying the impact force onto the cement behind the window. In this way, the cement may be broken.

[0055] For the purposes of describing and defining the present invention, it is noted that reference herein to a variable being a “function” of a parameter or another variable is not intended to denote that the variable is exclusively a function of the listed parameter or variable. Rather, reference herein to a variable that is a “function” of a listed parameter is intended to be open ended such that the variable may be a function of a single parameter or a plurality of parameters.

[0056] It is also noted that recitations herein of “at least one” component, element, etc., should not be used to create an inference that the alternative use of the articles “a” or “an” should be limited to a single component, element, etc. For example, the fluid jetting nozzle 118 may be a plurality of fluid jetting nozzles.

[0057] It is noted that recitations herein of a component of the present disclosure being "configured" or “programmed” in a particular way, to embody a particular property, or to function in a particular manner, are structural recitations, as opposed to recitations of intended use. More specifically, the references herein to the manner in which a component is "configured" or “programmed” denotes an existing physical condition of the component and, as such, is to be taken as a definite recitation of the structural characteristics of the component.

[0058] It is noted that terms like “preferably,” “commonly,” and “typically,” when utilized herein, are not utilized to limit the scope of the claimed invention or to imply that certain features are critical, essential, or even important to the structure or function of the claimed invention. Rather, these terms are merely intended to identify particular aspects of an embodiment of the present disclosure or to emphasize alternative or additional features that may or may not be utilized in a particular embodiment of the present disclosure.

[0059] For the purposes of describing and defining the present invention it is noted that the terms “substantially” and “approximately” are utilized herein to represent the inherent degree of uncertainty that may be attributed to any quantitative comparison, value, measurement, or other representation. The terms “substantially” and “approximately” are also utilized herein to represent the degree by which a quantitative representation may vary from a stated reference without resulting in a change in the basic function of the subject matter at issue.

[0060] One or more aspects of the present disclosure are described here. A first aspect of the present disclosure may include a bottomhole assembly for performing a sidetracking operation in a casing of a wellbore. The assembly includes a body, a fluid intensifier configured to receive fluid and configured to increase a pressure of the fluid, a fluid jetting nozzle associated with the body, a side arm, and a hook disposed on the body. The fluid jetting nozzle is fluidly coupled to the fluid intensifier and configured to receive pressurized fluid from the fluid intensifier. The fluid jetting nozzle is configured to cut a window into the casing via the pressurized fluid. The side arm movable between a closed position wherein the side arm is retracted and a guiding position wherein the side arm is extended. The side arm is configured to contact the casing in the guiding position to guide the body within the casing. The hook is configured to couple to the cut window and remove the cut window from the casing. [0061] A second aspect of the present disclosure may include the first aspect, wherein an end of the body is removably coupled to a guiding profile.

[0062] A third aspect of the present disclosure may include the first aspect and the second aspect, further including a drilling jar disposed within the body. The drilling jar is configured to generate an impact force onto the hook when activated.

[0063] A fourth aspect of the present disclosure may include any of the first aspect through the third aspect, further including a power supply operatively coupled to the fluid intensifier and configured to operatively drive the fluid intensifier.

[0064] A fifth aspect of the present disclosure may include any of the first aspect through the fourth aspect, further including an abrasive material supply and a mixing chamber fluidly coupled to the fluid intensifier and fluidly coupled to the fluid jetting nozzle. The mixing chamber is configured to receive abrasive material from the abrasive material supply, receive the pressurized fluid from the fluid intensifier, mix the pressurized fluid and the abrasive material, and provide the mixed pressurized fluid to the fluid jetting nozzle.

[0065] A sixth aspect of the present disclosure may include any of the first aspect through the fifth aspect, wherein the fluid jetting nozzle is disposed on a lower end of the body.

[0066] A seventh aspect of the present disclosure may include any of the first aspect through the sixth aspect, wherein the hook includes a plurality of drills movable between a retracted position wherein the plurality of drills are retracted within the body and a retrieval position wherein the plurality of drills are extended. The plurality of drills are configured to drill into the window to remove the window from the casing.

[0067] An eighth aspect of the present disclosure may include any of the first aspect through the seventh aspect, further including a second side arm movable between the closed position wherein the second side arm is retracted and the guiding position wherein the second side arm is extended. The second side arm is configured to contact the casing in the guiding position to guide the bottomhole assembly within the casing. Wherein a base portion of the side arm is positioned on a first side of the body, a base portion of the second side arm is positioned on a second side of the body, and the second side arm and the side arm co-operate to position the body within the casing. [0068] A ninth aspect of the present disclosure may include any of the first aspect through the eighth aspect, wherein the hook is positioned on the first side of the body.

[0069] A tenth aspect of the present disclosure may include a method for performing a sidetracking operation in a casing of a wellbore. The method includes guiding a body of a bottomhole assembly within the casing via a side arm extending from the body in contact with the casing. The method further includes descending the body to a cutting depth. The cutting depth having a predetermined depth within the casing for performing the sidetracking operation. The method further includes operatively driving a fluid intensifier of the bottomhole assembly to a power supply of the bottomhole assembly. The method further includes increasing a pressure of a fluid in the fluid intensifier. The method further includes cutting a window into the casing via a fluid jetting nozzle associated with the body, the fluid jetting nozzle being fluidly coupled to the fluid intensifier and configured to receive pressurized fluid from the fluid intensifier. The method further includes coupling a hook disposed on the body into the cut window and removing the cut window from the casing.

[0070] An eleventh aspect of the present disclosure may include a tenth aspect, further including removably coupling a guiding profile to a lower end of the body and removably coupling the guiding profile to the casing and removably decoupling the guiding profile from the lower end.

[0071] A twelfth aspect of the present disclosure may include any of the tenth aspect through the eleventh aspect, further including programming a cutting path of the fluid jetting nozzle.

[0072] A thirteenth aspect of the present disclosure may include any of the tenth aspect through the twelfth aspect, further including operatively coupling a telemetry system to the body, the fluid jetting nozzle, the power supply, and the fluid intensifier.

[0073] A fourteenth aspect of the present disclosure may include any of the tenth aspect through the thirteenth aspect, further including providing abrasive material from an abrasive material supply disposed in the bottomhole assembly to a mixing chamber disposed in the bottomhole assembly, providing the pressurized fluid from the fluid intensifier to the mixing chamber, mixing the pressurized fluid and the abrasive material in the mixing chamber, and providing the mixed pressurized fluid to the fluid jetting nozzle. [0074] A fifteenth aspect of the present disclosure may include any of the tenth aspect through the fourteenth aspect, further including generating an impact force by activating a drilling jar disposed in the body onto the hook.

[0075] A sixteenth aspect of the present disclosure may include any of the tenth aspect through the fifteenth aspect, wherein operatively coupling the hook to the cut window is performed via a plurality of drills, the plurality of drills being movable between a retracted position wherein the plurality of drills are retracted within the body and a retrieval position wherein the plurality of drills are extended.

[0076] A seventeenth aspect of the present disclosure may include any of the tenth aspect through the sixteenth aspect, further including guiding the body within the casing via a second side arm configured to contact the casing. Wherein a base portion of the side arm is positioned on a first side of the body, a base portion of the second side arm is positioned on a second side of the body, and the second side arm and the side arm co-operate to position the body within the casing.

[0077] An eighteenth aspect of the present disclosure, may include a bottomhole assembly for performing a sidetracking operation in a casing of a wellbore. The assembly including a body, a fluid intensifier, a fluid jetting nozzle associated with the body, a side arm, a hook disposed on the body, and a telemetry system. The fluid intensifier is configured to receive fluid and is configured to increase a pressure of the fluid. The fluid jetting nozzle is fluidly coupled to the fluid intensifier and is configured to receive pressurized fluid from the fluid intensifier. The side arm is movable between a closed position, wherein the side arm is retracted and a guiding position wherein the side arm is extended, the side arm is configured to contact the casing in the guiding position to guide the body within the casing. The telemetry system is communicatively coupled to the body, to the fluid intensifier, to the fluid jetting nozzle, and to the side arm. The telemetry system is configured to communicate with the body to descend the body to a cutting depth. The cutting depth being a predetermined depth within the casing for performing the sidetracking operation. The telemetry system is further configured to communicate with the fluid jetting nozzle to cut a window into the casing via the pressurized fluid. The telemetry system is further configured to communicate with the hook to couple to the cut window and remove the cut window from the casing. [0078] A nineteenth aspect of the present disclosure may include the eighteenth aspect, wherein the telemetry system is communicatively coupled to a drilling jar disposed within the body, and wherein the telemetry system communicates with the drilling jar to generate an impact force onto the body.

[0079] A twentieth aspect of the present disclosure may include any of the eighteenth aspect and the nineteenth aspect, wherein the telemetry system is communicatively coupled to an abrasive material supply and to a mixing chamber fluidly coupled to the fluid intensifier and fluidly coupled to the fluid jetting nozzle. The telemetry system communicates with the mixing chamber to receive abrasive material from the abrasive material supply, receive the pressurized fluid from the fluid intensifier, mix the pressurized fluid and the abrasive material, and provide the mixed pressurized fluid to the fluid jetting nozzle.

[0080] Having described the subject matter of the present disclosure in detail and by reference to specific embodiments thereof, it is noted that the various details disclosed herein should not be taken to imply that these details relate to elements that are essential components of the various embodiments described herein, even in cases where a particular element is illustrated in each of the drawings that accompany the present description. Further, it will be apparent that modifications and variations are possible without departing from the scope of the present disclosure, including, but not limited to, embodiments defined in the appended claims. More specifically, although some aspects of the present disclosure are identified herein as preferred or particularly advantageous, it is contemplated that the present disclosure is not necessarily limited to these aspects.

[0081] It is noted that one or more of the following claims utilize the term “wherein” as a transitional phrase. For the purposes of defining the present invention, it is noted that this term is introduced in the claims as an open-ended transitional phrase that is used to introduce a recitation of a series of characteristics of the structure and should be interpreted in like manner as the more commonly used open-ended preamble term “comprising.”