ROTATING ANNULAR PREVENTER AND METHODS OF USE THEREOF
A rotating annular preventer having a body with at least one seal housed within the body, and the at least one seal being at least one rotatable seal. The at least one seal can seal the annulus around a tubular in the rotating annular preventer by actuating a first seal around the tubular by a piston and/or rotating a second seal sealingly engaged with the tubular, as the tubular is rotated, since the rotating annular preventer is configured to do both. An outlet, located axially below the piston in the side of the body, can divert fluid from an annulus surrounding the tubular.
Exploration for, location of, and extraction of subterranean fluids, including hydrocarbon fluids, typically involves drilling operations to create a well. Drilling operations, particularly drilling operations involving rotary drilling, often utilize drilling fluids, also called muds, for a variety of reasons including lubrication, removal of cuttings and other matter created during the drilling process, and to provide sufficient pressure to ensure that fluids located in subterranean reservoirs do not enter the borehole, or wellbore, and travel to the surface of the earth. Fluids located in subterranean reservoirs are under pressure from the overburden of the earth formation above them. Specialized equipment is used to provide control of all fluids used or encountered in the drilling of a well.
Conventionally, well pressure control equipment may include a blowout preventer (BOP) stack that sits atop of a wellhead. The BOP stack may include ram BOP(s) and an annular BOP. An annular preventer is a large valve used to control wellbore fluids. In this type of valve, the sealing element resembles a large rubber doughnut that is mechanically squeezed inward to seal on either pipe (drill collar, drillpipe, casing, or tubing) or the openhole. The ability to seal on a variety of pipe sizes is one advantage the annular preventer has over the ram blowout preventer. Most BOP stacks contain at least one annular preventer at the top of the BOP stack, and one or more ram-type preventers below.
Above the annular BOP is often a managed pressure drilling/underbalance drilling rotating control device (RCD)/rotating head. The RCD/rotating head is a pressure-control device used during drilling for the purpose of making a seal around the drillstring while the drillstring rotates. Essentially, the RCD/rotating head is a diverter with holding pressure capability. This device is intended to contain hydrocarbons or other wellbore fluids and prevent their release to the atmosphere by diverting flow through an outlet below the sealing element.
SUMMARY OF DISCLOSUREIn one or more embodiments, a rotating annular preventer may include a body; at least one seal housed within the body and configured to seal against a tubular extending through the rotating annular preventer by actuation of a piston, wherein the at least one seal comprises at least one rotatable seal; and an outlet in the side of the body to divert fluid from an annulus surrounding the tubular, wherein the outlet is located axially below the piston.
In one or more embodiments, a method for using a rotating annular preventer may include placing a tubular in the rotating annular preventer about an central axis of the rotating annular preventer; sealing off the annulus around the tubular with the rotating annular preventer by actuating a first seal around the tubular by a piston and/or rotating a second seal sealingly engaged with the tubular as the tubular is rotated, the rotating annular preventer being configured to do both; and opening a valve to redirect a fluid in the annular around the tubular out an outlet flow line that is below the first seal being actuated by the piston.
This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.
Embodiments of the present disclosure are described below in detail with reference to the accompanying figures. Like elements in the various figures may be denoted by like reference numerals for consistency. Further, in the following detailed description, numerous specific details are set forth in order to provide a more thorough understanding of the claimed subject matter. However, it will be apparent to one having ordinary skill in the art that the embodiments described may be practiced without these specific details. In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description.
While annular BOPs and rotating control device (RCD)/rotating heads are conventionally two separate pieces of equipment used in control of an oil well, embodiments of the present disclosure may allow for the integration of the functionalities provided by the two together into a single body/device. Such integrated device may be referred to as a rotating annular preventer (RAP). Conventionally, an annular preventer is mainly used in well control scenarios to strip in and out the tubulars; however, a major drawback of the annular preventer, in the field today, is the inability to divert fluid, necessitating the use of a choke below the annular preventer. Further, conventionally a rotating head is used in drilling in under or at or over balanced scenarios or under managed pressure drilling, where the fluid is maintained within a pressurized system, rather than being open to the atmosphere. The RCD/rotating head seals against the tubular as it rotates within the device (during drilling) and diverts the returned fluid from the annulus to a MPD manifold. Thus, in one or more embodiments, a rotating annular preventer is an integrated managed pressure drilling/underbalanced drilling rotating control device/rotating head and well control annular blowout preventer. The integration may take various forms, including the use of a single body/bonnet and/or integration of internal parts.
By integrating the functionalities into a single device, in one or more embodiments, the RAP of the present disclosure may divert fluid, seal off the annulus while tubulars are moving up and downwards and/or rotating, seal off the wellbore when there are no tubulars in it, and/or strip in and out the tubulars in well control situation. The RAP can be used on and off while drilling through different formations and depths when is needed, or tripping in and out or stripping in and out while securing the well. The RAP as a single piece equipment may be installed, for example, at the top of the BOP stack, in the place of a conventional annular preventer, with a bell nipple being installed at the top of the RAP.
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Piston 104 may be hydraulically actuated to engage and disengage the AP seal 103, thereby opening and closing the annular preventer 102. A wellbore pressure 105 may optionally be used in conjunction with the hydraulically actuated piston 104 to close the AP seal 103 around the tubular 100. The wellbore pressure 105 can be applied directly or indirectly to the hydraulically actuated piston 104 to help close the AP seal 103 around the tubular 100 by any passageway or fluid communication between the annulus and the piston 104. By hydraulically actuating piston 104, piston 104 is not dependent on the wellbore pressure 105, thus allowing the piston 104 to engage and disengage the AP seal 103 under any wellbore pressure 105. Additionally, an outlet flow line 106 is disposed below AP seal 103, such as at a bottom of the annular preventer 102, to allow a flow of wellbore fluid out of the annular preventer 102. Once an AP seal 103 seals around tubular 100 and valve 107 is opened, the outlet flow line 106 will divert wellbore fluid from the annulus (not shown) since the AP seal 103 has closed the annular flowpath around tubular 100. Additionally, the valve 107 may be a hydraulically remote valve (HCR) to open and close the valve hydraulically and remotely. Furthermore, a check valve 111 or a one way valve, to prevent reverse flow of the fluid, may be used in conjunction with the valve 107. As seen by
Further, a bearing assembly 108 is disposed on the piston 104 at an outer radial surface thereof. The bearing assembly 108 allows for the rotation of piston 104 (and AP seal 103 via its engagement with piston 104) within the annular preventer 102, unlike conventional annular BOPs. While not specifically illustrated, it is envisioned that heat generated by the bearing assembly 108 may be transferred therefrom with the use of a circulating hydraulic lubricant oil system. The rotation of the AP seal 103 and piston 104 may result from rotation of tubular 100 sealed at an inner surface of AP seal 103. Thus, as tubular 100 rotates, the sealing engagement between tubular 100 and AP seal 103 and the engagement between AP seal 103 and piston 104 causes the AP seal 103 and piston 104 to rotate along with tubular 100. Thus, actuation of the piston 104 may cause seal 103 to seal against the tubular either in well control situations or when it is desired to drill under managed pressure. Additionally, at least one or more hydraulic lines (not shown) are coupled to the piston 104 for actuation thereof. In one or more embodiments, the piston 104 may have one hydraulic line (not shown) configured to disengage the piston 104 from the AP seal 103 and another hydraulic line (not shown) to engage the piston 104 to the AP seal 103.
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Further, as described above, annular preventer 102 also includes an outlet flow line 106 that, upon opening of valve 107, may divert wellbore fluid from the annulus upon sealing engagement of AP seal 103 with tubular 100 (or itself if no tubular is present). Additionally, a check valve 111 or a one way valve, to prevent reverse flow of the fluid, may be used in conjunction with the valve 107. As seen by
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While the above described embodiments show a single seal (that is rotatable) in order to combine the annular BOP and RCD functionalities into a single packing element, the present disclosure is not so limited. Rather, embodiments may also use, within a single body, multiple seals (at least one of which is rotatable) and achieve a device of the present disclosure. For example, according to one or more embodiments, a rotating annular preventer 400 has functionalities for a rotating control device in an upper region 401 and an annular preventer in a lower region 402 in a single body 410. Further, while body 410 is described as being the outer housing for the internal rotating annular preventer 400 components, it is also appreciated that the body may have multiple components, such as a body and bonnet, etc. that may be attached together to form a complete outer structure. The precise arrangement of such components is not a limitation on the present disclosure. The rotating control device 401 is axially above the annular preventer 402.
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As a tubular 100 rotates within the rotating annular preventer 400, the RCD seal 403 will rotate based on the sealing engagement of the RCD seal 403 and the tubular 100. The engagement of RCD seal 403 with tubular 100 occurs when the annular preventer 402 (described below) is open. Specifically, RCD seal 403 engages against tubular 100 extending through a bore of the rotating annular preventer 400 due to wellbore pressure 105. Wellbore pressure 105 may be transmitted through any passageway or the like that can provide fluid communication between the annulus and RCD seal 403. Upon engaging with tubular 100, RCD seal 403 is intended to contain hydrocarbons or other wellbore fluids and prevent their release to the atmosphere. Rather, engagement of RCD seal 403 with tubular 100 will result in wellbore fluids being diverted from the annulus through the outlet flow line 106 (upon opening of valve 107) so that drilling may continue under managed pressure. Outlet flow line 106 is located towards the bottom end of body 410.
Below rotating control device upper region 401 and above outlet flow line 106 is annular preventer lower region 402, which provides well control functionality. In one or more embodiments, the annular preventer lower region 402 includes an annular preventer (AP) seal 103 that is positioned about the central axis 101 (and an optional tubular 100). When open, AP seal 103 may have an internal diameter that, at a minimum, is the same as a ram BOP stack (not shown), thereby allowing easy passage of the tubulars therethrough without any restriction. Adjacent to a bottom or outer radial surface of AP seal 103 is a piston 104 having a wedge face. Further,
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Thus, there are a number of variations that may be made on the rotating annular preventer of the present disclosure. The single device may integrate the conventionally two separate devices/functionalities by just sharing the bonnet/body for the RCD and annular preventer, or the device may integrate internal components. Further, as also described above, the various sealing elements (also referred to in the art as a packing assembly) can be operated as an active sealing system, passive sealing system, or with combinations thereof. While the rotating annular preventer integrates two functions of well control and managed pressure drilling, it is understood that the dynamic pressure rating of the device (considered while moving tubulars) may be less than static rating (considered when no tubulars are present) due to movement of tubulars (either axially or rotationally).
Further, as described, embodiments of the present disclosure may include one or more hydraulic lines, such as for the hydraulically actuated piston, for cooling of a bearing assembly, etc. In one or more embodiments, hydraulic lines for opening and closing the annular preventer (such as by moving the piston) can be distinct from the lubricant oil lines. Further, it is also envisioned that hydraulic lines for operating the RAP in well control situations can be separate from hydraulic lines for operating the RAP during managed pressure drilling and underbalanced drilling operations. Sealing elements can be divided into separate compartments for MPD/UBD operation or well control operation. When the RAP is not needed, it will be fully opened by applying hydraulic pressure to position/reposition its piston axially downward, allowing the retraction/repel of the sealing elements (packing assembly). When RAP is needed, the piston will move upward to the closed position and cause the sealing elements (packing assembly) to squeeze inward towards any object or itself in order to seal off completely the annulus or even open wellbore. These and other actuations and tasks can be mechanized and automated to fulfill all the required tasks from health monitoring and preventive maintenance as well as operation and well construction. Specifically, the entire process can be mechanized/automated and a software used to control the operation.
It is also envisioned that the sealing pressure of the one or more sealing elements can be adjusted and regulated (either automatically or manually), particularly for passing different shape of tubulars (for example, due to collars, stabilizers, tool joints, etc.) under a variety of wellbore pressures. In an active or combination system, when different geometry of tubulars are passing through the sealed elements under different wellbore conditions, the pressure of hydraulic oil system can be adjusted and regulated automatically or manually to ensure the optimum proper sealing of the annulus.
While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.
Claims
1. A rotating annular preventer, comprising:
- a body;
- at least one seal housed within the body and configured to seal against a tubular extending through the rotating annular preventer by actuation of a piston, wherein the at least one seal comprises at least one rotatable seal; and
- an outlet in the side of the body to divert fluid from an annulus surrounding the tubular, wherein the outlet is located axially below the piston.
2. The rotating annular preventer of claim 1, wherein a single seal is both the at least one rotatable seal and the seal actuated by the piston.
3. The rotating annular preventer of claim 2, further comprising a bearing assembly disposed on an outer radial surface of the single seal, thereby providing for the single seal to be rotatable.
4. The rotating annular preventer of claim 2, further comprising a bearing assembly disposed on an outer radial surface of the piston, thereby providing for the single seal to be rotatable.
5. The rotating annular preventer of claim 2, further comprising a first bearing assembly disposed on an outer radial surface of the piston and a second bearing assembly disposed on an outer radial surface of the single seal, thereby providing for the single seal to be rotatable.
6. The rotating annular preventer of claim 1, wherein the body further comprises an upper portion containing a rotating control device and a lower portion containing an annular preventer.
7. The rotating annular preventer of claim 6, wherein the rotating control device comprises the at least one rotatable seal and the annular preventer comprises the at least one seal actuated by the piston.
8. The rotating annular preventer of claim 7, further comprising a bearing assembly disposed on an outer radial surface of the at least one rotatable seal, thereby providing for rotation of the at least one rotatable seal.
9. The rotating annular preventer of claim 6, wherein the rotating control device comprises two rotatable seals.
10. The rotating annular preventer of claim 9, wherein the each of the two rotatable seals is rotatable due to a bearing assembly disposed on an outer radial surface of each of the two rotatable seals.
11. The rotating annular preventer claim 1, wherein the at least one seal is reinforced with a metallic material.
12. The rotating annular preventer of claim 1, further comprising at least one or more lubrication systems disposed in the body.
13. The rotating annular preventer of claim 1, wherein the outlet flow line further comprises at least one or more valves to open and close the outlet flow line.
14. A method for using a rotating annular preventer, comprising:
- placing a tubular in the rotating annular preventer about an central axis of the rotating annular preventer;
- sealing off the annulus around the tubular with the rotating annular preventer by actuating a first seal around the tubular by a piston and/or rotating a second seal sealingly engaged with the tubular as the tubular is rotated, the rotating annular preventer being configured to do both; and
- opening a valve to redirect a fluid in the annular around the tubular out an outlet flow line that is below the first seal being actuated by the piston.
15. The method of claim 14, wherein the first seal and the second seal are the same seal.
16. The method of claim 14, wherein the rotation of the at least one seal is by a bearing assembly.
17. The method of claim 14, further comprising lubricating the at least one seal with a lubricant to help enable rotation with or without a bearing assembly.
18. The method of claim 14, further comprising directing the annulus fluid from the outlet flow line to a fluid transport line.
19. The method of claim 14, wherein the first seal actuated by the piston is axially below the second seal rotated with the tubular.
20. The method of claim 14, wherein the second seal is sealingly engaged with the tubular by a wellbore pressure.
Type: Application
Filed: Jul 18, 2017
Publication Date: Jan 24, 2019
Inventor: Babak Bob Arefi (Spring, TX)
Application Number: 15/652,627