This application claims priority to European Patent Application No. EP 15306906.7, entitled “WELLHEAD ASSEMBLY WITH INTERNAL CASING HANGER PACK-OFF”, filed on Dec. 1, 2015, which is herein incorporated by reference in its entirety.
This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the presently described embodiments. 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 embodiments. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.
To meet consumer and industrial demand for natural resources, companies often invest significant amounts of time and money in finding and extracting oil, natural gas, and other subterranean resources from the earth. Particularly, once a desired subterranean resource such as oil or natural gas is discovered, drilling and production systems are often employed to access and extract the resource. These systems may be located onshore or offshore depending on the location of a desired resource. Further, such systems generally include a wellhead assembly mounted on a well through which the resource is accessed or extracted. These wellhead assemblies may include a wide variety of components, such as various casings, valves, hangers, pumps, fluid conduits, and the like, that facilitate drilling or production operations.
As will be appreciated, various tubular strings can be run into wells through wellhead assemblies. For instance, wells are often lined with casing that generally serves to stabilize the well and to isolate fluids within the wellbore from certain formations penetrated by the well (e.g., to prevent contamination of freshwater reservoirs). Such casing is frequently hung in a well from a hanger in the wellhead assembly and cemented into place within the well. During a cement job, cement can be pumped down a casing string in a well, out the bottom of the casing string, and then up the annular space surrounding the casing string. The cement is then allowed to set in the annular space.
A pack-off or pack-off assembly is used to seal the hanger to the wellhead. Traditionally, hanger pack-off assemblies—which seal the annular space below the hanger from the wellbore above the hanger—reside between the inner surface of the wellhead and the outer surface of the hanger. In certain instances, the hanger may have been landed such that the hanger's central axis is at an angle or “tilted” with respect to the wellhead's and wellbore's central axis. Unfortunately, this increases the effort required to install the hanger pack-off, as the space on one side of the tilted hanger may not be sufficient to accommodate the annular pack-off assembly.
Certain aspects of some embodiments disclosed herein are set forth below. It should be understood that these aspects are presented merely to provide the reader with a brief summary of certain forms the invention might take and that these aspects are not intended to limit the scope of the invention. Indeed, the invention may encompass a variety of aspects that may not be set forth below.
Embodiments of the present disclosure generally relate to hanger and pack-off assemblies used in wellheads. In some instances, the pack-off assembly seals against an inner surface of the wellhead body and an inner surface of the hanger. This sealing configuration facilitates sizing of the upper portion of the hanger's (e.g., casing hanger's, tubing hanger's) outer surface diameter to closely match the head's (e.g., casing head's, tubing head's) inner surface diameter. The close tolerances between the two surfaces guides the hanger during installation, reducing the likelihood the hanger will be tilted when landed. It further, in certain embodiments, can reduce the trapping of debris between the hanger and wellhead body, improving the wellhead assembly's resistance to wear.
Various refinements of the features noted above may exist in relation to various aspects of the present embodiments. Further features may also be incorporated in these various aspects as well. These refinements and additional features may exist individually or in any combination. For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination. Again, the brief summary presented above is intended only to familiarize the reader with certain aspects and contexts of some embodiments without limitation to the claimed subject matter.
These and other features, aspects, and advantages of certain 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:
Specific embodiments of the present disclosure are described below. In an effort to provide a concise description of these 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.
When introducing elements of various embodiments, the articles “a,” “an,” “the,” and “said” are intended to mean that there are one or more of the elements. The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements. Moreover, any use of “top,” “bottom,” “above,” “below,” other directional terms, and variations of these terms is made for convenience, but does not require any particular orientation of the components.
Turning now to the present figures, a system 10 is illustrated in
The wellhead hangers 22 can be positioned on landing shoulders 24 within hollow wellhead bodies (e.g., within the tubing and casing heads). These landing shoulders 24 can be integral parts of tubing and casing heads or can be provided by other components, such as sealing assemblies or landing rings disposed in the tubing and casing heads. Each of the hangers 22 can be connected to a tubular string, such as a tubing string 26 or a casing string 28, suspended within the well 14. The well 14 can include a single casing string 28 or include multiple casing strings 28 of different diameters. Any suitable devices or machines may be used to run tubular strings into wells through wellheads and install hangers attached to the tubular strings in the wellheads.
For example, a top drive coupled to a hanger running tool 30 can be used to land the casing hanger 22 in the casing head 18, as shown in
The hanger 22 is lowered into the head 18 until a sloped surface on the hanger engages a load shoulder 24 that's on the head and that supports the hanger 22 and the casing string 28 threaded to the hanger 22. The load shoulder 24 prevents further downward movement of the hanger 22, while the complementary profile of the hanger and head prevents lateral movement of the hanger, particularly towards the top of the hanger 22. This, in turn, prevents tilting of the hanger when exposed to lateral forces or moments. The close fit and complementary nature of these two surfaces also retards the ingress of debris between these two components, even before installation of pack-off (as is discussed below). Indeed, this arrangement, in comparison to traditional designs, may benefit by not requiring a washing step to clean the casing hanger before installation of the pack-off (again, as discussed below).
Casing strings 28 are often cemented in place within the well. In some instances, cement is pumped down a casing string 28 and into an annular space around the casing string 28. A plug can then be pumped down the casing string 28 with a displacement fluid (e.g., drilling mud) to generally push additional cement in the casing string out the bottom and into the annular space. As the cement fills the annular space, it displaces drilling mud present in the annular space before cementing began. This causes the displaced drilling mud to flow up the well to the wellhead. The illustrated hanger 22 include one or more passages 40, often called flutes or flow-by holes, that allow for drilling mud and/or cement to flow around the casing hanger.
The pack-off's inner diameter “C” may be sized to the equal to or greater than the casing string's inner diameter “D.” This provides for “full-bore access” to the casing string, and ensures the pack-off does not restrict the passage of down-hole tools into the wellbore and casing string 28, for instance.
A locking mechanism 54 secures the pack-off assembly 42 to the casing head 18, causing, in certain embodiments, the pack-off assembly to block upward movement of the hanger 22 and to squeeze (energize) some of the pack-off's seals. For example, a pack-off running tool, which is not shown but the likes of which are well understood, may be used to lower the pack-off assembly 42 onto the hanger. Complementary surfaces 56 and 58 on the hanger 22 and pack-off assembly 42 engage to land the pack-off at the desired location in the head, similar in operation to the landing shoulder 24 controlling the location of the casing hanger 22 within the casing head 18.
Once landed, the pack-off running tool (not shown) can be used to actuate the locking mechanism 54. The right side of
The secured pack-off assembly provides sealing benefits to wellbore pressure potentially in the cemented annulus 43. For example, the close fit between the pack-off assembly's seals and respective seal surfaces limits gaps through which the elastomeric seals might extrude. In turn, because extrusion is limited, when wellbore pressures apply axially on the seals, the seals radially expand, improving the sealing between the casing hanger and casing head.
While the aspects of 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 have been described in detail herein. But it should be understood that the invention is not intended to be limited to the particular forms disclosed. Rather, the invention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the following appended claims.
Number | Date | Country | Kind |
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15306906.7 | Dec 2015 | EP | regional |