BACKGROUND
Embodiments of the present disclosure relate generally to the field of drilling and processing of wells. More particularly, present embodiments relate to a system and method for operating a moveable BOP transport skid to move a BOP stack from one well to another where multiple wells are at a same well site.
Some well sites can include two or more wells, such as with an array of wells. To drill and produce fluids from the various wells at the well site, a rig and various support equipment (e.g. a Blowout Preventer (BOP) stack) can be transported between the wells in the array to perform the subterranean operations. A BOP stack is large and heavy, and currently requires various support equipment (e.g. cranes, lifts, wheeled vehicles, etc.) to hoist a BOP stack from one well head at one location, transport the BOP stack to another location at the well site, and attach the BOP stack to another well head at other location. Therefore, improvements in BOP stack handling systems are continually needed.
SUMMARY
In accordance with an aspect of the disclosure, a system for conducting a subterranean operation is provided, where the system can include a blowout preventer (BOP) stack, a chassis coupled to the BOP stack, and one or more transport devices coupled to the chassis and configured to transport the chassis and the BOP stack from a first location to a second location.
In accordance with another aspect of the disclosure, a method for conducting subterranean operations is provided, where the method can include operations of mounting a blowout preventer (BOP) stack to a chassis, the chassis comprising one or more transport devices, and moving, via the one or more transport devices, the chassis from a first location to a second location.
BRIEF DESCRIPTION OF THE DRAWINGS
These and other features, aspects, and advantages of present embodiments will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein:
FIG. 1A is a representative v-door side view of a rig with a moveable BOP transport skid, in accordance with certain embodiments;
FIG. 1B is a representative off-driller's side view of a rig with a moveable BOP transport skid, in accordance with certain embodiments;
FIG. 2A is a representative top view of a moveable BOP transport skid, in accordance with certain embodiments;
FIG. 2B is a representative side view of a moveable BOP transport skid, in accordance with certain embodiments;
FIG. 2C is a representative side view of a moveable BOP transport skid with a BOP stack in various rotated positions, in accordance with certain embodiments;
FIG. 2D is a representative top view of a moveable BOP transport skid with a BOP stack in various rotated positions, in accordance with certain embodiments;
FIG. 2E is a representative front view of a moveable BOP transport skid with a BOP stack in a raised position above a well head, in accordance with certain embodiments;
FIG. 2F is a representative front view of a moveable BOP transport skid with a BOP stack in an engaged position with a well head, in accordance with certain embodiments;
FIG. 3A is a representative top view of another moveable BOP transport skid, in accordance with certain embodiments;
FIG. 3B is a representative side view of the moveable BOP transport skid of FIG. 3A, in accordance with certain embodiments;
FIG. 3C is a representative side view of the moveable BOP transport skid of FIG. 3A with a BOP stack in a vertical position, in accordance with certain embodiments;
FIG. 4A is a representative top view of yet another moveable BOP transport skid, in accordance with certain embodiments;
FIG. 4B is a representative side view of the moveable BOP transport skid of FIG. 4A, in accordance with certain embodiments;
FIG. 4C is a representative side view of the moveable BOP transport skid of FIG. 4A with a BOP stack in a vertical position, in accordance with certain embodiments;
FIG. 5A is a representative top view of yet another moveable BOP transport skid, in accordance with certain embodiments;
FIG. 5B is a representative side view of the moveable BOP transport skid of FIG. 5A, in accordance with certain embodiments;
FIG. 5C is a representative side view of the moveable BOP transport skid of FIG. 5A with a BOP stack in a vertical position, in accordance with certain embodiments;
FIG. 6A is a representative partial cross-sectional view of a moveable BOP transport skid at one well location at a well site, in accordance with certain embodiments;
FIG. 6B is a representative partial cross-sectional view of a moveable BOP transport skid in transit between one well location to another well location at a well site, in accordance with certain embodiments.
FIG. 6C is a representative partial cross-sectional view of a moveable BOP transport skid at another well location at a well site, in accordance with certain embodiments.
DETAILED DESCRIPTION
Present embodiments provide a system and method for transporting a BOP stack between multiple well locations at a well site using a dedicated transport skid. The transport skid can include a controller in a sealed housing that moves with the transport skid. The controller can control the operation of the transport skid. The aspects of various embodiments are described in more detail below.
As used herein, the terms “comprises,” “comprising,” “includes,” “including,” “has,” “having,” or any other variation thereof, are intended to cover a non-exclusive inclusion. For example, a process, method, article, or apparatus that comprises a list of features is not necessarily limited only to those features but may include other features not expressly listed or inherent to such process, method, article, or apparatus. Further, unless expressly stated to the contrary, “or” refers to an inclusive-or and not to an exclusive-or. For example, a condition A or B is satisfied by any one of the following: A is true (or present) and B is false (or not present), A is false (or not present) and B is true (or present), and both A and B are true (or present).
The use of “a” or “an” is employed to describe elements and components described herein. This is done merely for convenience and to give a general sense of the scope of the invention. This description should be read to include one or at least one and the singular also includes the plural, or vice versa, unless it is clear that it is meant otherwise.
The use of the word “about”, “approximately”, or “substantially” is intended to mean that a value of a parameter is close to a stated value or position. However, minor differences may prevent the values or positions from being exactly as stated. Thus, differences of up to ten percent (10%) for the value are reasonable differences from the ideal goal of exactly as described. A significant difference can be when the difference is greater than ten percent (10%).
FIG. 1A is a representative side view of a rig 10 (which can be referred to as a V-door side) with a moveable BOP transport skid 100 positioned just outside the off-drillers side of the rig 10. A BOP stack 120 has been rotated to a vertical position in preparation for aligning with a well head 160 (not shown, see FIGS. 6A-6C). The rig 10 can include a rig substructure 12 that supports the rig 10 on the surface 6. The rig 10 can have a rig floor 16 on top of the rig substructure 12. A derrick 14 can extend above the rig floor 16 to support tubular handling activities (e.g. pipe handler, top drive, crown block, etc.) during a subterranean operation (e.g. drilling, production, etc.). A choke manifold 20 can be positioned on the rig floor 16 as shown.
FIG. 1B is a representative side view of a rig 10 (which can be referred to as an off-driller's side) with a moveable BOP transport skid 100 positioned at a center of the off-driller's side of the rig 10. It should be understood that the BOP transport skid 100 can enter the substructure 12 from any of the sides, not only the non-driller's side, if the substructure 12 is configured to allow entrance of the BOP transport skid 100. The BOP transport skid 100 can be used to transport a BOP stack from one well center to another well center, or between other locations like a test site, a storage location, a transport vehicle. A top drive 22 is shown proximate the rig floor 16. A catwalk 24 can be used to present tubulars to or retrieve tubulars from the rig floor 16. It should be noted that the X-Y-Z coordinate axes are indicated in FIGS. 1A and 1B, where the X-Y-Z coordinate axes are relative to the rig floor 16. The rig floor 16 forms an X-Y plane with the Z axis being substantially perpendicular with the rig floor 16.
It should be noted that the X-Y-Z coordinate axes are indicated in FIGS. 2A-5C, where the X-Y-Z coordinate axes are relative to the chassis 102. The top of the chassis 102 forms an X-Y plane with the Z axis being substantially perpendicular with the top of the chassis 102. As used herein, “horizontal,” “horizontal position,” or “horizontal orientation” refers to a position that is substantially parallel with the X-Y plane. As used herein, “vertical,” “vertical position,” or “vertical orientation” refers to a position that is substantially perpendicular relative to the X-Y plane.
FIG. 2A is a representative top view of a moveable BOP transport skid 100, that can include a chassis 102, multiple transport devices 130, and a BOP support frame 122 that can carry a BOP stack 120. The BOP transport skid 100 can also include one or more control consoles 104, 106 for an operator 30 to operate the BOP transport skid 100. In this example, four transport devices 130 are mounted to a left side of the chassis 102 and four transport devices 130 are mounted to a right side of the chassis 102, with left being toward the bottom of the figure, and right being toward the top of the figure. These transport devices 130 can cooperate together to propel the BOP transport skid 100 along the surface 6. The transport devices 130 can be controlled to move the BOP transport skid 100 forward or backward (arrows 94), or the transport devices 130 can be used to steer the BOP transport skid 100 to the left or right (arrows 96), or the transport devices 130 can be used to rotate the BOP transport skid 100. Each of the transport devices 130 can include a vertical actuator moveably coupled to a pad that can engage the surface 6. As the vertical actuator is extended, it pushes against the pad and lifts the chassis 102 from the surface 6. A horizontal actuator can then be used to move the vertical actuator and the chassis 102 relative to the pad, thereby propelling the BOP transport skid 100. Each of the transport devices 130 can be rotated (arrows 80) to steer the BOP transport skid 100 to the right or left as the BOP transport skid 100 is being propelled forward or backward. One or more of the transport devices 130 can be rotated to steer the BOP transport skid 100. The transport devices 130 can be rotated (arrows 80) by up to 360 degrees to support lateral movement in the X-Y plane as well as rotating the BOP transport skid 100. Rotation of the BOP transport skid 100 can be about any Z-axis, such at the center axis 70 of the BOP stack when the BOP stack is in a vertical position, a Z-axis along the chassis 102, etc.
The BOP transport skid 100 can be operated to move along the surface 6 by a controller 114 (in a housing 116) that can receive operator 30 inputs from either of the control consoles 104, 106. The rear control console 104 can be used by the operator 30 if he wishes to ride along with the BOP transport skid 100 as it moves along the surface 6. The side control console 106 can be used by the operator 30 if he wishes to walk beside the BOP transport skid 100 as it moves along the surface 6. The side control console 106 can be stowed away on an arm that is rotated to be parallel to the long side of the chassis 102. If the operator 30 wishes to use the side control console 106, the operator 30 can rotate the arm (arrows 82) from a position parallel to the long side of the chassis 102 to a position perpendicular to the long side of the chassis (as seen in FIG. 2A). Rotation of the arm can form an arc of radius R1, which can be equal to the length of the arm. The transport devices 130 can include hydraulic actuators which may require a hydraulic power unit (HPU) 108 w/a reservoir be included on the BOP transport skid 100. The HPU 108 can also be used to support other actuators on the BOP transport skid 100 (e.g. actuator 110 in FIG. 2B). Wireless or wired controls are possible.
In operation, the BOP stack 120 (held by the BOP support frame 122) is usually oriented in a horizontal position relative to the chassis 102 during transport of the BOP transport skid 100 along the surface 6. With the BOP stack 120 secured in the horizontal position, the operator 30 can operate the transport devices 130 to propel the BOP transport skid 100 along the surface 6. In an unselected state, the vertical actuator of the transport device 130 is retracted causing the respective pad to be lifted from the surface 6 and allows the chassis 102 to rest on the surface 6. In a selected state, the vertical actuator of the transport device 130 is extended causing the respective pad to engage the surface 6 and lift the chassis 102 from the surface 6.
With all transport devices 130 in a selected state, the BOP transport skid 100 can be held above the surface 6, and the horizontal actuator of each respective transport device 130 can be actuated to move the chassis 102 horizontally relative to the pad, thereby propelling the BOP transport skid 100 along the surface 6, since the pads are engaged with the surface and the chassis moves horizontally relative to the pads. The vertical actuator of each respective transport device 130 can then be retracted to rest the chassis 102 back on the surface 6 and lift the pads from the surface 6. The pads can then be reset to their initial horizontal position before the movement of the BOP transport skid 100, thereby positioned to go again. This can be called a “step” when the pads lift the chassis 102 from the surface 6, propel the chassis 102 relative to the pads horizontally (i.e. in the X-Y plane relative to the chassis 102), and set the chassis 102 back down on the surface to allow the pad positions to be reset. As the operator 30 initiates multiple steps, the BOP transport skid 100 can be transported from one well head to another well head. Again, the BOP transport skid 100 can be steered as it is transported along the surface 6 by selectively rotating (arrows 80) various ones of the transport devices 130.
FIG. 2B is a representative side view of a moveable BOP transport skid 100. Four transport devices 130 can be seen on this right side of the chassis 102 of the BOP transport skid 100. An operator 30 can operate the BOP transport skid 100 via the control console 104. The BOP support frame 122 is shown holding a BOP stack in a substantially horizontal position. The BOP stack can have a central axis 70 that can also be the center axis of the connection flange 126. This flange 126 can be used to connect to a flange 26 at a top of a well head when the BOP stack is transported to and aligned with the well head. The BOP support frame 122 can be rotationally mounted to the chassis 102 via pivot 112. The BOP support frame 122 can also be rotationally coupled to an actuator 110, which can be used to rotate the BOP stack to a substantially vertical position from the horizontal position. The transport devices 130 can lift the chassis up and down in the Z-direction (arrows 98) as the BOP transport skid 100 takes steps to propel the BOP transport skid 100 along the surface (arrows 94).
FIG. 2C is a representative side view of a moveable BOP transport skid with a BOP stack in various positions as it is rotated about the pivot 112 via the actuator 110 between substantially horizontal and substantially vertical positions. As the actuator 110 is extended, the BOP support frame 122 rotates (arrows 90) about the pivot 112 toward a vertical position. As the actuator 110 is retracted, the BOP support frame 122 rotates (arrows 90) about the pivot 112 toward a horizontal position. Once the BOP stack 120 is rotated to a substantially vertical position, a BOP alignment system 124 can be used to align the BOP stack 120 with the well head. More particularly, the BOP alignment system 124 can be used to align the flange 126 of the BOP stack with the flange 26 which can be at the top of the well head.
The BOP alignment system 124 can raise and lower the BOP stack in the Z-direction (arrows 88), move the BOP stack 120 horizontally in an X-Y plane (arrows 84 and 86), and rotate the BOP stack (arrows 92) in order to align the flange 126 with the flange 26. The BOP alignment system 124 can also tilt that BOP stack 120 away from the Z-axis to cause the flange 126 to be co-planar (i.e. substantially parallel) to the flange 26. If the BOP stack 120 needs further tilting about the Y-axis (i.e. about pivot 112), the actuator 110 can be used to further tilt the BOP stack. When the flanges 126, 26 are aligned with each other (i.e. the center axis 70 aligned with the center axis 72), the BOP stack can be lowered to the well head, thereby engaging the flange 126 with the flange 26. When these flanges 126, 26 are fastened together, the BOP stack can support subterranean operations at the well head. The BOP alignment system 124 can include various actuators to allow manipulation of the BOP stack relative to the chassis 102 and/or the support frame 122 to align the BOP stack with the well head.
FIG. 2D is a representative top view of a moveable BOP transport skid 100 with a BOP stack in various rotated positions about the central axis 70. Only the chassis 102 of the moveable BOP transport skid 100 is shown for clarity. The BOP alignment system 124 can rotate the BOP stack 120 (arrows 92) as needed to align a bolt pattern 128 in the flange 126 with a bolt pattern 28 in the flange 26.
FIG. 2E is a representative front view of a moveable BOP transport skid 100 with a BOP stack 120 in a raised position above a well head. In this example, the BOP stack 120 has been aligned with the well head, such that the central axis 70 of the BOP stack flange 126 is aligned with the central axis 72 of the well head flange 26, and the bolt pattern 128 of the flange 126 is aligned with the bolt pattern 28 of the flange 26. The BOP stack 120 can now be lowered to the well head.
FIG. 2F is a representative front view of a moveable BOP transport skid 100 with a BOP stack 120 lowered to engage the well head. The flange 126 has been lowered to engage the flange 26 and fasteners can be installed to attach the BOP stack to the well head.
FIGS. 3A-3C are representative views of another moveable BOP transport skid 100. This skid 100 is similar to the skid 100 in the FIGS. 2A-2F, except that the BOP transport skid 100 in FIGS. 3A-3C has four transport devices 130 (two on each side of the chassis 102) instead of eight transport devices 130 (four on each side of the chassis 102). The discussion above related to the BOP transport skid 100 of FIGS. 2A-2F is applicable to the BOP transport skid 100 of FIGS. 3A-3C with the like reference numerals indicating the same element and/or feature. For example, the BOP alignment system 124 described above is also used in the BOP transport skid 100 of FIGS. 3A-3C to align the BOP stack 120 with the well head. The transport devices 130 can be hydraulically actuated devices with the pads, vertical actuator, and horizontal actuator as described above.
FIG. 3A is a representative top view of another moveable BOP transport skid 100 with four transport devices 130. Each device 130 can be a hydraulically actuated walker that can propel the BOP transport skid 100 along the surface similar to the operation described above.
FIG. 3B is a representative side view of the moveable BOP transport skid 100 of FIG. 3A, with the BOP stack 120 held in the BOP support frame 122 in a horizontal position. A test stump 127 can be attached to the flange 126 of the BOP stack 120 to support pressure testing of the BOP stack 120. When it is desired to attach the BOP stack 120 to a well head, the test stump 127 can be removed.
FIG. 3C is a representative side view of the moveable BOP transport skid 100 of FIG. 3A, with a BOP stack 120 held in the BOP support frame 122 in a vertical position. The BOP alignment system 124 can be used to align the flange 126 of the BOP stack 120 with the flange 26 of the well head for connection to the well head. However, when a pressure test is desired, the test stump 127 can remain attached to the BOP stack 120. This testing can be performed at locations other than the well head location.
FIGS. 4A-4C are representative views of another moveable BOP transport skid 100. This skid 100 is similar to the skid 100 in the FIGS. 2A-2F, except that the BOP transport skid 100 in FIGS. 4A-4C has four transport devices 130 (two on each side of the chassis 102) that are different transport devices 130. The discussion above related to the BOP transport skid 100 of FIGS. 2A-2F is applicable to the BOP transport skid 100 of FIGS. 4A-4C with the like reference numerals indicating the same element and/or feature. For example, the BOP alignment system 124 described above is also used in the BOP transport skid 100 of FIGS. 4A-4C to align the BOP stack 120 with the well head.
However, in this example, the transport devices 130 are continuous tread devices 130. Each continuous tread device 130 can include a continuous tread 132 that travels on the outside of a drive motor 134 and multiple guide pulleys. As the drive motor 134 rotates, the continuous tread 132 is forced to travel around a perimeter of the respective continuous tread device 130. When the continuous tread devices 130 are engaged with the surface 6 and the chassis 102 is lifted above the surface 6, the BOP transport skid 100 can be propelled along the surface 6 by driving the continuous treads to move the BOP transport skid 100 relative to the surface.
FIG. 4A is a representative top view of a moveable BOP transport skid 100 with four transport devices 130. Each device 130 can be hydraulically actuated to lower the device 130 into engagement with the surface 6 and lift the chassis 102 from the surface 6.
FIG. 4B is a representative side view of the moveable BOP transport skid 100 of FIG. 4A, with the BOP stack 120 held in the BOP support frame 122 in a horizontal position. With the chassis 102 lifted off the surface 6, the continuous tread devices 130 can be used to propel the BOP transport skid 100 forward or backward (arrows 94) by driving the continuous treads 132 with the respective drive motors 134. If the operator wishes to steer the BOP transport skid 100 to the right or left (arrows 96), the operator 30 can adjust the speeds of the individual drive motors 134 to cause the treads 132 on one side to move faster or slower than the treads 132 on the other side of the chassis 102. The operator 30 can also cause the transport devices 130 on one side of the chassis 102 to drive in one direction with the transport devices 130 on the opposite side of the chassis 102 to drive in an opposite direction which can cause the BOP transport skid 100 to rotate. The continuous tread devices 130 can also be rotated (like arrows 80 in FIG. 3A) to steer the BOP transport skid 100 to the right or left.
FIG. 4C is a representative side view of the moveable BOP transport skid 100 of FIG. 4A, with a BOP stack 120 held in the BOP support frame 122 in a vertical position. When the destination is reached, the continuous tread devices 130 can be retracted to allow the chassis 102 to again rest on the surface 6. The extended position of the continuous tread device 130 is indicated by the reference numeral 140. The extended position can lift the chassis 102 from the surface 6 by a distance L1. The retracted position of the continuous tread device 130 is indicated by the reference numeral 142. Unlike the transport devices 130 of FIGS. 2A-3C, the continuous tread devices 130 do not have to retract for each step and pad positions do not need to be reset. The continuous tread devices 130 can be extended, and the BOP transport skid 100 can be propelled from one well head to the next well head without having to retract the continuous tread devices 130. The continuous tread devices 130 can be retracted when the destination is reached. However, it is not a requirement that the continuous tread devices 130 remain extended the entire distance between the two well heads. The continuous tread devices 130 can be retracted as desired during the transport of the BOP transport skid 100 to the new location.
FIGS. 5A-5C are representative views of another moveable BOP transport skid 100. This skid 100 is similar to the skid 100 in the FIGS. 3A-3C, except that the BOP transport skid 100 in FIGS. 5A-5C has two transport devices 130 (one on each side of the chassis 102) that are different versions of the transport devices 130 than those in FIGS. 2A-3C. The discussion above related to BOP transport skid 100 of FIGS. 2A-2F is applicable to the BOP transport skid 100 of FIGS. 5A-5C with the like reference numerals indicating the same element and/or feature. For example, the BOP alignment system 124 described above is also used in the BOP transport skid 100 of FIGS. 5A-5C to align the BOP stack 120 with the well head.
However, in this example, the transport devices 130 are continuous tread devices 130. Each continuous tread device 130 can include a continuous tread 132 that travels on the outside of a drive motor 134 and multiple guide pulleys. As the drive motor 134 rotates, the continuous tread 132 is forced to travel around a perimeter of the respective continuous tread device 130. In this example, the continuous tread devices 130 can remain engaged with the surface 6 and the chassis 102 can be held above the surface 6. The BOP transport skid 100 can be propelled along the surface 6 by driving the continuous treads to move the BOP transport skid 100 relative to the surface.
FIG. 5A is a representative top view of a moveable BOP transport skid 100 with two transport devices 130. Each device 130 can be attached to the chassis 102 and hold the chassis 102 above the surface 6. Therefore, the continuous tread devices 130 are not raised and lowered in this example. However, in another embodiment, the continuous tread devices 130 of this BOP transport skid 100 can be hydraulically raised and lowered to selectively engage and disengage the chassis 102 with the surface 6, as in the other embodiments above.
FIG. 5B is a representative side view of the moveable BOP transport skid 100 of FIG. 5A, with the BOP stack 120 held in the BOP support frame 122 in a horizontal position. With the chassis 102 held above the surface 6, the continuous tread devices 130 can be used to propel the BOP transport skid 100 forward or backward (arrows 94) by driving the continuous treads 132 with the respective drive motors 134. If the operator wishes to steer the BOP transport skid 100 to the right or left (arrows 96), the operator 30 can adjust the speeds of the individual drive motors 134 to cause the tread on one side to move faster or slower than the tread on the other side of the chassis 102. The operator 30 can also cause the transport device 130 on one side of the chassis 102 to drive in one direction with the transport device 130 on the opposite side of the chassis 102 to drive in an opposite direction which can cause the BOP transport skid 100 to rotate.
FIG. 5C is a representative side view of the moveable BOP transport skid 100 of FIG. 5A, with a BOP stack 120 held in the BOP support frame 122 in a vertical position. The BOP alignment system 124 can be used to align the BOP stack 120 with the well head to enable connection of the BOP stack 120 to the well head.
It should be noted that the X-Y-Z coordinate axes indicated in FIGS. 6A-6C, are X-Y-Z coordinate axes that are relative to the surface 6. The surface 6 can form an X-Y plane with the Z axis being substantially perpendicular with the surface 6.
FIG. 6A is a representative partial cross-sectional view of a moveable BOP transport skid 100 at a well location 160 at a well site 150. The well site 150 can include two or more well locations 160, with each well location 160 having a well head. In this example, the BOP transport skid 100 is positioned at the first well location 160 which includes a wellbore 170 with a casing string 180 installed in the wellbore 170. The casing string 180 is not required, but the well location should include a well head or other structure to which a BOP stack 120 can be installed. In FIG. 6A, the BOP stack 120 is attached to the well head at the first well location 160. The following description discloses the operations related to using the moveable BOP transport skid 100 to transport the BOP stack 120 without the use of additional support equipment, such as cranes, pulleys, wheeled transport vehicles, etc. The rig 10 is not shown in FIGS. 6A-6C for clarity. The rig 10 can also be transported from the first well location 160 to the second well location 160 by various means, but this is not the subject of this disclosure.
Once operations utilizing the BOP stack are halted at the first well location 160, the BOP stack can be disconnected from the well head at the first well location 160 and transported to a second well location 160. BOP transport skid 100 can transport the BOP stack from the first well location 160 to the second well location 160. With the BOP stack 120 held by the BOP support frame 122 in a vertical position, the BOP stack can be disconnected from the well head at the first well location 160, by unfastening the flange 126 of the BOP stack from the flange 26 of the well head at the first well location 160. The BOP stack 120 can then be lifted up and off the flange 26 and rotated to a horizontal position for transport along the surface 6.
FIG. 6B is a representative partial cross-sectional view of the moveable BOP transport skid 10 in transit between the first well location 160 to a second well location 160. Any of the embodiments above can be used to transport the BOP stack 120 from the first well location 160 to a second well location 160. It should be understood that the BOP stack 120 can be transported in a reverse direction by transporting the BOP stack from the second well location 160 to the first well location 160.
FIG. 6C is a representative partial cross-sectional view of the moveable BOP transport skid 100 at the second well location 160. The second well location 160 can also include a wellbore 170 and a casing string 180 installed in the wellbore 170. When the BOP transport skid 100 arrives at the second well location 160, the BOP stack 120 can be rotated to a vertical position again, and the BOP alignment system 124 can be used to align the center axis 70 of the BOP stack 120 with the center axis 72 of the well head at the second well location 160. With the flange 126 aligned and co-planar with the flange 26, the BOP alignment system 124 can lower the BOP stack 120 such that the flange 126 engages the flange 26. The flanges 126, 26 can be attached together, thereby attaching the BOP stack 120 to the well head at the second well location 160.
Regarding FIGS. 6A-6C, these show a usual transportation of the BOP stack 120 between well heads. However, the BOP transport skid 100 can be used to transport the BOP stack between various other locations. For example, the BOP transport skid 100 can receive the BOP stack 120 from a transport vehicle that has transported the BOP stack to the well site. Once the BOP stack 120 has been transferred to the BOP transport skid 100, the BOP transport skid 100 can then transport the BOP stack to any other location, such as a well head, a test site (where a pressure test of the BOP stack in either a horizontal or vertical position can be performed), a storage location (where support equipment can off-load the BOP stack 120 from the BOP transport skid 100.
VARIOUS EMBODIMENTS
Embodiment 1
A system for conducting a subterranean operation, the system comprising:
a blowout preventer (BOP) stack;
a chassis coupled to the BOP stack; and
one or more transport devices coupled to the chassis and configured to transport the chassis and the BOP stack from a first location to a second location.
Embodiment 2
The system of embodiment 1, wherein the first location is a first well head and the second location is a second well head.
Embodiment 3
The system of embodiment 1, wherein the first location is a well head and the second location is a test location for testing the BOP stack.
Embodiment 4
The system of embodiment 1, wherein the first location is a well head and the second location is a storage location.
Embodiment 5
The system of embodiment 1, wherein the first location is a test location for testing the BOP stack and the second location is a well head.
Embodiment 6
The system of embodiment 1, wherein the first location is a storage location and the second location is a test location for testing the BOP stack.
Embodiment 7
The system of embodiment 1, wherein the chassis is configured to rotate the BOP stack, relative to the chassis, between substantially horizontal and substantially vertical positions.
Embodiment 8
The system of embodiment 7, wherein the chassis further comprises a BOP alignment system, and wherein the BOP alignment system is configured to align the BOP stack to a well head.
Embodiment 9
The system of embodiment 8, wherein the alignment of the BOP stack to the well head aligns a first flange of the BOP stack to a second flange of the well head.
Embodiment 10
The system of embodiment 9, wherein the alignment of the BOP stack to the well head aligns a bolt pattern of the first flange to a bolt pattern of the second flange.
Embodiment 11
The system of embodiment 8, wherein the alignment of the BOP stack comprises movement of the BOP stack in an X-Y plane relative to the chassis, with the BOP stack oriented in the substantially vertical position.
Embodiment 12
The system of embodiment 8, wherein the alignment of the BOP stack comprises rotation of the BOP stack about a central axis of a first flange of the BOP stack, with the BOP stack oriented in the substantially vertical position.
Embodiment 13
The system of embodiment 8, wherein the alignment of the BOP stack comprises the BOP stack being tilted relative to an X-Y plane of the chassis, with the BOP stack oriented in the substantially vertical position.
Embodiment 14
The system of embodiment 8, wherein the alignment of the BOP stack comprises the BOP stack being lifted or lowered relative to the chassis, with the BOP stack oriented in the substantially vertical position.
Embodiment 15
The system of embodiment 1, wherein each of the one or more transport devices is a hydraulic walker.
Embodiment 16
The system of embodiment 15, wherein the hydraulic walker is configured to lift the chassis from a surface and propel the chassis forward or backward.
Embodiment 17
The system of embodiment 1, wherein each of the one or more transport devices is a continuous tread device.
Embodiment 18
The system of embodiment 17, wherein the continuous tread device comprises a motor and a continuous tread, wherein the motor is configured to drive the continuous tread and propel the chassis forward or backward or in rotation, and wherein the continuous tread device is configured to lift and lower the chassis from and onto a surface.
Embodiment 19
The system of embodiment 17, wherein the continuous tread device comprises a motor and a continuous tread, wherein the motor is configured to drive the continuous tread and propel the chassis forward or backward or in rotation, and wherein the continuous tread device is configured to support the chassis above a surface.
Embodiment 20
A method for conducting a subterranean operation, the method comprising:
mounting a blowout preventer (BOP) stack to a chassis, the chassis comprising one or more transport devices; and
moving, via the one or more transport devices, the chassis from a first location to a second location.
Embodiment 21
The method of embodiment 20, further comprising:
at the first location, receiving the BOP stack in a horizontal orientation; and
at the second location, rotating the BOP stack from the substantially horizontal position to the substantially vertical position; and
mounting the BOP stack to a well head.
Embodiment 22
The method of embodiment 20, further comprising:
at the first location, receiving the BOP stack in a horizontal orientation; and
at the second location, rotating the BOP stack from the substantially horizontal position to the substantially vertical position; and
testing the BOP stack, with the BOP stack having a test stump attached to the BOP stack.
Embodiment 23
The method of embodiment 20, further comprising:
at the first location, attaching the BOP stack to the chassis, removing the BOP stack from a well head in the substantially vertical orientation, and rotating the BOP stack from the substantially vertical position to the substantially horizontal position; and
at the second location, transferring the BOP stack from the chassis to another transport device.
Embodiment 24
The method of embodiment 20, further comprising rotating the BOP stack between a substantially horizontal position and a substantially vertical position.
Embodiment 25
The method of embodiment 24, further comprising:
at the first location, rotating the BOP stack from the substantially vertical position to the substantially horizontal position; and
at the second location, rotating the BOP stack from the substantially horizontal position to the substantially vertical position.
Embodiment 26
The method of embodiment 25, further comprising:
at the second location, aligning a first connection flange of the BOP stack with a second connection flange of a well head at the second location.
Embodiment 27
The method of embodiment 26, wherein the aligning the BOP stack further comprises rotating the BOP stack relative to the chassis and the well head.
Embodiment 28
The method of embodiment 26, wherein the aligning the BOP stack further comprises translating the BOP stack in an X-Y plane relative to the chassis and the well head.
Embodiment 29
The method of embodiment 26, wherein the aligning the BOP stack further comprises tilting the BOP stack relative to the chassis and the well head.
Embodiment 30
The method of embodiment 26, wherein the aligning the BOP stack further comprises aligning a bolt pattern of the BOP stack with a bolt pattern of the well head.
Embodiment 31
The method of embodiment 26, wherein the aligning the BOP stack further comprises lowering the BOP stack relative to the chassis and the well head at the second location, thereby engaging the first connection flange with the second connection flange.
While the present disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and tables and have been described in detail herein. However, it should be understood that the embodiments are not intended to be limited to the particular forms disclosed. Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims. Further, although individual embodiments are discussed herein, the disclosure is intended to cover all combinations of these embodiments.
Patent Application
20210032959
