Patent Grant
11053764
The present disclosure relates to blowout preventers. More specifically, the present disclosure relates to ram type blowout preventers that have improved hang off capabilities. Even more specifically, the present disclosure relates to ram type blowout preventers that have improved hang off capabilities.
This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.
In well drilling operations such as in the oil and gas industry, blowout preventers (BOPS) are an important safety “valve” for well pressure control. BOPs typically use elastomer packer elements for sealing around a pipe. In addition to providing sealing functionality, some BOPs may provide hang off capability. Hang off is generally when the BOP supports the weight of that portion of the drill string below the BOP. The axial hang off load can be supported by a tool joint resting on the closed BOP. Ordinarily certain types of ram BOPs can be designed to provide hang off capability.
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 determining or limiting the scope of the claimed subject matter as set forth in the claims.
According to some embodiments, a ram assembly is described that is used in a ram type blowout preventer configured to form a seal against a tubular member. The blowout preventer can a fixed size ram preventer a variable bore ram preventer. The ram assembly includes a packer assembly and a ram body. The packer assembly includes at least one elastomeric packer member having a substantially U-shaped face to form the seal against the tubular member. The ram body is configured to house said packer assembly and when actuated in a ram actuation direction towards the tubular member pushes said U-shaped face on the packer assembly against the tubular member. The ram body includes an upper U-shaped face generally aligned with the U-shaped face of the packer assembly and an upper centralizing lobe shaped and positioned to aid in moving the tubular member towards a central position with respect to the U-shaped faces of the packer assembly and ram body. The U-shaped face of the ram body and/or the upper centralizing lobe are shaped to improve hang off capacity of the preventer.
According to some embodiments, the improvement of hang off capacity is due at least in part on a tapered section formed at an intersection of the ram body U-shaped face and the upper centralizing lobe. According to some embodiments, the hang-off is improved compared to an otherwise identical preventer having a semi-circular U-shaped face that intersects directly with a main front face of the upper centralizing lobe. The tapered section can include a planar surface that is at an angle between 5 and 90 degrees from the ram actuation direction. In some cases the angle is between 10 and 75 degrees, 15 and 60 degrees, or 20 and 45 degrees. In some embodiments the angle is about 30 degrees.
According to some embodiments, the improvement of hang off capacity comes from the shape of the ram body U-shaped face and/or the upper centralizing lobe spreading the axial load of a tool joint over a larger area of the ram body above and adjacent to the U-shaped face of the ram body.
As used herein, the phrases “ram preventer,” “ram-type preventer,” “ram blowout preventer” and “ram-type blowout preventer” refer to a blowout preventer in which the pressure-control functions are achieved through the operation of hydraulically operated ram sets.
As used herein, the phrases “variable bore ram preventer” and “variable bore ram blowout preventer” refer to ram-type blowout preventers that are configured to enable sealing on two or more different pipe diameter sizes. Examples of pipe diameter sizes includes the international standard American Petroleum Institute (API) for steel drill-pipes for use in drilling and production operations in petroleum and natural gas industries. The API 5 DP specifies drill pipes in the following sizes: 2⅜″, 2⅞″, 3½″, 4″, 4½″, 5″, 5″½, and 6⅝″. In the case of API 5 DP drill pipe sizes, a variable bore ram preventer are configured to enable sealing over a diameter range of at least ½″. In some cases variable bore ram preventers such as Cameron's VBR preventers are configured to seal on pipes with diameters that differ by 1⅞″ or more.
As used herein, the phrase “hang off” in the context of ram-type blowout preventers refers to when the BOP supports the weight of that portion of the drill string below the BOP. The axial hang off load is designed to be supported by a tool joint resting on the closed BOP.
The subject disclosure is further described in the following detailed description, and the accompanying drawings and schematics of non-limiting embodiments of the subject disclosure. The features depicted in the figures are not necessarily shown to scale. Certain features of the embodiments may be shown exaggerated in scale or in somewhat schematic form, and some details of elements may not be shown in the interest of clarity and conciseness.
One or more specific embodiments of the present disclosure will be described below. These described embodiments are only exemplary of the present disclosure. Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another. Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.
The particulars shown herein are for purposes of illustrative discussion of the embodiments of the present disclosure only. In this regard, no attempt is made to show structural details of the present disclosure in more detail than is necessary for the fundamental understanding of the present disclosure, the description taken with the drawings making apparent to those skilled in the art how the several forms of the present disclosure may be embodied in practice. Like reference numerals represent similar or identical parts throughout the several views of the drawings.
According to some embodiments, a ram type BOP that has substantial hang off capacity is described.
Downhole operations, such as drilling, are carried out by a tubular string 16 (e.g., drillstring) that is supported by the derrick 21 and extends from the platform 20 through the riser 14, through the BOP stack assembly 100, and into the wellbore 11. In this example, a downhole tool 17 is shown connected to the lower end of the tubular string 16. In general, the downhole tool 17 may comprise any suitable downhole tool(s) for drilling, completing, evaluating, and/or producing the wellbore 11 including, without limitation, drill bits, packers, cementing tools, casing or tubing running tools, testing equipment and/or perforating guns. During downhole operations, the string 16, and hence the tool 17 coupled thereto, may move axially, radially, and/or rotationally relative to the riser 14 and the BOP stack assembly 100.
The BOP stack assembly 100 is mounted to the wellhead 30 and is designed and configured to control and seal the wellbore 11, thereby containing the hydrocarbon fluids (liquids and gases) therein. In this example, the BOP stack assembly 100 comprises a lower marine riser package (LMRP) 110 and a BOP or BOP stack 120. The LMRP 110 includes a riser flex joint 111, a riser adapter 112, one or more annular BOPs 113, and a pair of redundant control units or pods. A flow bore 115 extends through the LMRP 110 from the riser 14 at the upper end of the LMRP 110 to the connection at the lower end of the LMRP 110. The riser adapter 112 extends upward from the flex joint 111 and is coupled to the lower end of the riser 14. The flex joint 111 allows the riser adapter 112 and the riser 14 connected thereto to deflect angularly relative to the LMRP 110, while wellbore fluids flow from the wellbore 11 through the BOP stack assembly 100 into the riser 14. The annular BOPs 113 each include annular elastomeric sealing elements that are mechanically squeezed radially inward to seal on a tubular extending through the LMRP 110 (e.g., the string 16, casing, drillpipe, drill collar, etc.) or seal off the flow bore 115. Thus, the annular BOPs 113 have the ability to seal on a variety of pipe sizes and/or profiles, as well as perform a “Complete Shut-off” (CSO) to seal the flow bore 115 when no tubular is extending therethrough.
A main bore 125 extends through the BOP stack 120. In addition, the BOP stack 120 includes a plurality of axially stacked ram BOPs 121. Each ram BOP 121 includes a pair of opposed rams and a pair of actuators that actuate and drive the matching rams. In the example depicted, the BOP stack 120 includes four ram BOPs 121. An upper ram can include opposed blind shear rams or blades for severing the tubular string 16 and sealing off the wellbore 11 from the riser 14. The three lower ram BOPs 121 include the opposed pipe rams for engaging the string 16 and sealing the annulus around the tubular string 16. According to some embodiments, one or more of the ram BOPs 121 can be variable bore ram (VBR) type BOPs. In other embodiments, the BOP stack (e.g., the stack 120) may include a different number of rams, different types of rams, one or more annular BOPs, or combinations thereof. According to some embodiments, one or more of the ram BOPs 121 include improved hang off capability.
The ram body 310 includes a semi-circular face 324 that can roughly match the sealing face 338 of packer member 334 and is shaped to accommodate a tubular (not shown) disposed in the wellbore that can be sealed against. Note that although the face 324 is referred to here and shown as semi-circular, in general the face is generally U-shaped and does not have to be strictly semi-circular in shape. On one side of the ram body 310, an upper centralizer lobe 320 is shown, and on the other side of the ram body 310 a lower centralizer lobe 322 is shown. The upper and lower centralizer lobes 320 and 322 are shaped such that when paired with an opposing ram body with similar or identical upper and lower centralizer lobes (see, e.g.
In addition to housing the packer assembly 230 and centralizing a tubular as described, supra, ram body 310 can also be used to support an axial load, or hang off, where the BOP supports the weight of the portion of the drill string that is below the BOP. In such cases the axial hang off load is supported by a tool joint resting on the closed BOP. When being used for hang off, a shoulder of a tool joint will come into contact with the upper edge of the semi-circular face 324. In prior art variable bore ram blowout preventers, such as shown in commonly owned U.S. Pat. No. 8,727,303, incorporated by reference herein, the upper centralizer lobe 320 is shaped as shown by dotted outline 370. In such prior art designs, the front edge of the upper centralizer lobe 320 extends until it intersects with the semi-circular face 324. It has been found that in some cases during a hang off, a relatively large axial load is concentrated onto the “inner corner” of the centralizer lobe where it intersects with the semi-circular face. In some cases during a hang off, virtually the entire hang off load is concentrated onto four locations of prior art the ram bodies, two of which are the inner corners of the upper centralizer lobes of the two opposing ram bodies. According to some embodiments, a tapered section, 350, is provided on the upper centralizer lobe 320 of the ram body 310. The shape of tapered section 350 allow for the axial load of the tool joint shoulder to be effectively spread over a much larger area of ram body 310, namely along a large portion of the upper edge of the semi-circular face 324.
According to some embodiments, the ram assembly 228 and ram body 310 are used in a variable bore ram preventer, which is configured to seal around pipes of more than one size. According to some embodiments the diameter range of the different pipe sizes is at least than ½ inch, according to some embodiments the diameter range is at least 1 inch, and according to yet some other embodiments, the diameter range is at least 1½ inches. According to some embodiments, the ram assembly 228 and ram body 310 are used in a non-variable bore ram preventer (for fixed-size ram preventor) that is configured to seal only around a single pipe size. Note that even for a single pipe size there is a relatively small diameter range due to diameter tolerances. In the case of API SDP drill pipes the tolerances can be +/−0.79 mm for pipe sizes 4 inches and smaller, and +1.0%, −0.5% of diameter for sizes greater than 4 inches. Thus the diameter range for a single pipe size can be as high as 2-3 mm or about 1/10 inches even for fixed-size rams preventers.
While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. However, it should be understood that the disclosure is 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.
The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical. Further, if any claims appended to the end of this specification contain one or more elements designated as “means for” or “step for” performing a function, it is intended that such elements are to be interpreted under 35 U.S.C. 112(f). However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. 112(f).
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| Number | Date | Country | |
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