Patent Application
20250059846
This disclosure relates generally to oilfield equipment and more particularly to systems and methods for a well re-entry tool to be used with oilfield equipment.
Oilfield equipment may include a tubing hanger re-entry tool to provide access and service, such as wireline services, coil tubing, or fluid intervention for a tubing hanger or other assembly in a wellhead or horizontal tree. A tubing hanger is a device which is attached to the topmost tubing joint in the wellhead to support the tubing string in the oilfield equipment. The tubing hanger typically is located in the horizontal tree, tubing head, or wellhead, with components incorporating a sealing system to ensure that the tubing conduit and annulus are hydraulically isolated. A tubing hanger re-entry tool can enable removal and replacement of a tubing hanger and production tubing (or other tubing) from an associated horizontal tree, tubing head, or wellhead. A tubing hanger re-entry tool can engage with the tubing hanger. Upon engagement, the tubing hanger re-entry tool may be used to remove or to replace downhole completion components including isolation barrier valves replaces traditional wireline plugs. However, debris may build-up over time which can impact access to the well interface latching profile.
In at least one embodiment, a system for a re-entry tool to be used with oilfield equipment is disclosed. A stinger that includes flushing holes to enable fluid for flushing through the re-entry tool and into one or more of an Xmas tree head, tubing hanger, or crown plug, is provided in the system. The system includes one or more sleeves external to the stringer. The one or more sleeves include flushing slots to enable circulation of the fluid from the Xmas tree head, tubing hanger, or crown plug to an external environment relative to the Xmas tree head.
In at least one embodiment, a method for a re-entry tool to be used with oilfield equipment is disclosed. The method includes providing a stinger that has flushing holes within the re-entry tool. The method also includes enabling fluid for flushing through the stinger and into one or more of an Xmas tree head, tubing hanger, or crown plug. Further, the method includes enabling one or more sleeves that are external to the stringer and that have flushing slots to circulate the fluid from the Xmas tree head, tubing hanger, or crown plug to an external environment relative to the Xmas tree head.
Some of the features and benefits of the present disclosure having been stated, others will become apparent as the description proceeds when taken in conjunction with the accompanying drawings, in which:
While the disclosure will be described in connection with the preferred embodiments, it will be understood that it is not intended to limit the disclosure to that embodiment. On the contrary, it is intended to cover all alternatives, modifications, and equivalents, as may be included within the spirit and scope of the disclosure as defined by the appended claims.
The foregoing aspects, features and advantages of the present technology will be further appreciated when considered with reference to the following description of preferred embodiments and accompanying drawings, wherein like reference numerals represent like elements. In describing the preferred embodiments of the technology illustrated in the appended drawings, specific terminology will be used for the sake of clarity. The present technology, however, is not intended to be limited to the specific terms used, and it is to be understood that each specific term includes equivalents that operate in a similar manner to accomplish a similar purpose.
In at least one embodiment, a system for a re-entry tool ensures that debris can be sufficiently flushed from the latching profile to enable the tool to latch onto the tubing hanger enabling access to the completion tubing. For instance, to resolve issues described above, a system for a re-entry tool to be used with oilfield equipment is disclosed. A stinger that includes flushing holes to enable fluid for flushing of debris through the re-entry tool and into one or more of an Xmas tree head, tubing hanger, or crown plug, is provided in the system. The system includes one or more sleeves external to the stringer. The one or more sleeves include flushing slots to enable circulation of the fluid and debris from the Xmas tree head, tubing hanger, or crown plug to an external environment relative to the Xmas tree head. For instance, the fluid and debris can be returned, as part of the circulation, to the external environment where the returned fluid can be monitored for cleanliness.
In at least one embodiment, the re-entry tool may be used with a tubing hanger of an Xmas tree head that has an ability to tolerate a level of debris on top of the tubing hanger. The re-entry tool has capability to flush out the debris prior to landing the re-entry tool in the Xmas tree head. Further, the re-entry tool can facilitate well-intervention runs and well-kill, along with a capability to retrieve the tubing hanger. In at least one embodiment, the re-entry tool may be locked into an Xmas tree head at its internal profile. The re-entry tool may be sealed or affixed to the tubing hanger, temporarily to remove debris over the tubing hanger.
The re-entry tool can reduce non-productive time on well re-entry by circulating returned fluid and debris from the latching profile of the tubing hanger during re-entry scopes, where rigs may have otherwise experienced up to multiple days of non-productive down time due to failed attempts to land and to lock with other running tools that do not have flushing capability. The re-entry tool can lock into the Xmas tree head but not lock onto the tubing hanger latching profile. Instead, the re-entry tool has flushing ports therein to permit removal of debris, including mud and silt on top of the tubing hanger, such as on top of the latching profile.
Well re-entry for deep wells may be challenging to engage a latching profile of at the top of the tubing hanger due to debris. The latching profile is an interface that may be compromised due to debris and may make it difficult to perform latching connections there to. For example, silt and dirt may sit on top of the tubing hanger, at the latching profile. A Universal Running Tool (URT) may not be able to flush such debris or other tools may perform fully flush such debris resulting in a need for down time for manual or robotic flushing.
In at least one embodiment, a re-entry tool is part of a system including the Xmas tree head that can flush and circulate out dirt and other debris from the latching profile or the top of the tubing hanger with ports in the re-entry tool and holes in a sleeve of the re-entry tool to allow the debris to be circulated from the latching profile or crown plug of the tubing hanger within the Xmas tree head. This is so that a seal sub can be made up to a seal pocket of the tubing hanger and so that the area around a lock sleave of the tubing hanger is flushed clear. The re-entry tool can function to lock into an internal profile of an Xmas tree head with a high-integrity lock. The tubing hanger is already locked into the Xmas tree head at a lower locking part of the internal profile. As such, the re-entry tool enables a conduit for pressure retention and for force resistance between the tubing hanger, such as at a landing string, and the rig.
In at least one embodiment, the re-entry tool includes a reduced outer diameter to aid the flushing operation. A secondary unlock is enabled by an outer latch in an extended position to cause one or more dogs to engage an inner profile of the Xmas tree head. One or more slots are provided through one or more sleeves of the re-entry tool to improve the flushing operation, such as to allow fluid to be returned to an external environment with debris collected from the Xmas tree head. Further, the re-entry tool includes a stinger that is interchangeable. The one or more sleeves may include a reducer sleeve to suit different diameter Xmas tree heads. Further, the stinger is retractable and has flushing holes to enable part of the flushing operation. Still further, in at least one embodiment, one or more orientation keys of the re-entry tool enable alignment of each of the one or more sleeves with respect to each other and with respect to the stinger within the re-entry tool.
A blowout preventer (BOP) 130 provides prevention, pressure-related controls, as well as other functions in the oilfield equipment 100. The BOP 130 include seals that may be used for injectables, as well as pipe rams, shear rams, fluid rams, and other features to prevent any improper release of well fluids. There may be a ported slick joint having a cavity 112 disposed between one or more of the rams 102 of the BOP 130. Further, the cavity 112 may be associated with choke and kill lines 108A, 108B. There may be a further emergency BOP above the illustrated BOP 130. The emergency BOP may provide pressure control during a completion for running a re-entry tool 202.
In at least one embodiment, there may be one or more umbilical associated with the re-entry tool 106, such as within a riser 118 or along a landing string. An umbilical may support fluid removal or delivery, control, or communication to a surface outside the oilfield equipment 110. In at least one embodiment, however, the re-entry tool 202 allows fluid and debris to be returned from a profile 114 or other areas associated with the tubing hanger 104, and to the cavity 112. Then, the choke and kill lines 108A, 108B may be used to remove the fluid and debris to the surface that is outside the oilfield equipment 100. For example, the fluid and debris may be pumped into the cavity 112 of a ported slick joint, where the cavity is above the re-entry tool 202 may be above the ported slick joint. The fluid and debris may be further pumped up via at least the kill line 108A, which may be supported by a limited flow—by of a retainer valve.
In an example, one or more of the rams 102 of the BOP 130 may be closed around a casing associated with the riser 118 to enable the fluid and debris to the removed via the choke and kill lines 108A, 108B. In at least one embodiment, the tree head 110 may be exposed to the elements without aspects of an Xmas tree. Therefore, the tree head 110 may requiring flushing, at least as to the tubing hanger 104 and areas associated there with, prior to the re-entry tool 202 being used to operations supported there with. In at least one embodiment, a kill line 108A that is used for removal of the fluid and debris is a lower-most kill line 108A, but an umbilical that is outer to the landing string 122 may be also used for the removal of the fluid and debris. Further, a cavity 112 may be associated with the ported slick joint at a lower-most ram of the BOP 130. The landing string 122 may have a constriction or restrictive outer diameter to enable flow—by. In different embodiments, a crossover flange at a top of the re-entry tool 202 may be such that it is located below the cavity 112, at a level of a ram 102 of the BOP 130 or between one or more rams 102 of the BOP 130.
In at least one embodiment, the re-entry tool 202 includes one or more sleeves, such as a latch piston 204D (also referred to herein as a latch dog piston). The latch piston 204D is a sleeve comprising one or more flushing slots 210 to enable flushing there through. In at least one embodiment, fluid flows 212 through an inner portion 218 of the re-entry tool 202, through the stinger 204B, and out of a bottom 214 of the stinger 204B. In at least one embodiment, based in part on the stinger being extended or retracted, the fluid may be allowed or disallowed to flow through the one or more flushing holes 208. The fluid may pick up any debris from the Xmas tree head 110 and may provide it to an external environment 216, relative to the Xmas tree head 110. In at least one embodiment, the external environment 216, relative to the Xmas tree head 110, is, at least initially, a cavity 112 of a ported slick joint from where one or more of the choke and kill lines 108A, 108B are engaged to remove the fluid and debris. In at least one embodiment, the pumping action is for the entry of the fluid for flushing, through a landing string 118, but that is sufficient to cause the debris and removal fluid to flow through the cavity 112 of the ported slick joint, through at least the kill line 108A, and to an environment external to the tree head 110.
In at least one embodiment, the one or more sleeves also include a soft landing sleeve 226 and a latch dog support sleeve 228. The one or more sleeves are all external to the stringer 204B. Further, the one or more sleeves may each include the flushing slots, as illustrated with respect to the flushing slots 210 of the latch piston 204D. The flushing slots 210 enable return of the fluid from the Xmas tree head 110 to an external environment 216, relative to the Xmas tree head 110. In at least one embodiment,
In at least one embodiment, latch dogs 230 may be provided as an independent feature or as one of the one or more sleeves. The latch dogs 230 enable latching of the re-entry tool 202 with the latching profile 302 (in
In at least one embodiment,
In at least one embodiment, with the one or more break rings 1002 in the broken status 1052, annular tension may be applied from below the system to force the first or outer latch piston 204D to back up into the re-entry tool 202. In at least one embodiment, the annular tension is from an annular pressure that, in turn, causes or generates an unbalanced load on the first or outer latch piston 204D. This causes the outer latch piston 204D to retract and allows retrieval of the re-entry tool 202.
In at least one embodiment, the method 110 includes enabling (1108) one or more sleeves that are external to the stringer and that include flushing slots to return the fluid from the Xmas tree wellhead. A further step 1110 may be part of the removal step or may be distinctly provided to enable the removal in step 1108 to occur so that fluid is removed to an external environment relative to the Xmas tree head.
In at least one embodiment, the method 1100 may include a further step or a sub-step in which the stinger is capable of being in one or more of an extended position or a retracted position relative to the re-entry tool. This step may be by arrangement of one or more sleeves together using orientation keys prior to deployment of the re-entry tool. Therefore, in at least one embodiment, the method 1100 may include a further step or a sub-step for enabling, using one or more orientation keys, alignment of each of the one or more sleeves with respect to each other and with respect to the stinger within the re-entry tool.
In at least one embodiment, the method 1100 may include a further step or a sub-step of extending provided dogs through at least one of the one or more sleeves. In at least one embodiment, the method 1100 may include a further step or a sub-step of causing the provided dogs to engage the Xmas tree head to provide a locking of the re-entry tool with respect to the Xmas tree head. In at least one embodiment, the method 1100 may include a further step or a sub-step for providing a shoulder of the Xmas tree head and a surface of the re-entry tool. This may be performed at manufacture or by orientation of components in the system so that the shoulder provided is used for interfacing between components of the system herein. In at least one embodiment, the method 1100 may include a further step or a sub-step for landing the re-entry tool on the Xmas tree head at an interface of the shoulder and the surface. In at least one embodiment, the method 1100 may include a further step or a sub-step for enabling the flushing through the re-entry tool and into an Xmas tree head to occur prior to the landing, during the landing, and after the landing.
In at least one embodiment, the method 1100 may include a further step or a sub-step for allowing, using a stinger retainer cap, the stinger to be retained in a retracted position relative to the re-entry tool. In at least one embodiment, the method 1100 may include a further step or a sub-step for allowing the stringer to move to an extended position relative to the re-entry tool.
In at least one embodiment, the method 1100 may include a further step or a sub-step for allowing the stinger, in an extended position, to be received into a latching profile of the Xmas tree head. In at least one embodiment, the method 1100 may include a further step or a sub-step allowing landing of the re-entry tool on the latching profile of the Xmas tree head. The stinger can be moved from the extended position to a retracted position during the landing.
In at least one embodiment, the method 1100 may include a further step or a sub-step for enabling a first latch piston to be movable within the one or more sleeves. In at least one embodiment, the method 1100 may include a further step or a sub-step for causing, using the first latch piston, engagement or disengagement of provided dogs with respect to the Xmas tree head. Further, the engagement of the provided dogs, with respect to the Xmas tree head, enables overpull, pressure testing, and wireline operations using the re-entry tool. Further, disengagement of the provided dogs allows, at least in part, retraction of the re-entry tool.
In at least one embodiment, the method 1100 may include a further step or a sub-step for enabling a second latch piston of the one or more sleeves to be in one of a retracted position or an extended position. Further, in at least one embodiment, the method 1100 may include a step or a sub-step for enabling, in the extended position of the second latch piston, an unbalanced load in the re-entry tool to allow, at least in part, retraction of the re-entry tool.
In at least one embodiment, the method 1100 may include a further step or a sub-step for enabling one or more break rings within the one or more sleeves to be an unbroken status in normal operations of the re-entry tool. However, the method 1100 may include a further step or a sub-step for causing the one or more break rings to be in a broken status during an emergency operation in the re-entry tool. This then allows, in the broken status of the one or more break ring, a latch piston of the one or more sleeves to be in an extended position from a retracted position. Further, the extended position enables an unbalanced load in the re-entry tool and allows, at least in part as a result of the unbalanced load, retraction of the re-entry tool.
While techniques herein may be subject to modifications and alternative constructions, these variations are within spirit of present disclosure. As such, certain illustrated embodiments are shown in drawings and have been described above in detail, but these are not limiting disclosure to specific form or forms disclosed; and instead, cover all modifications, alternative constructions, and equivalents falling within spirit and scope of disclosure, as defined in appended claims.
When introducing elements of various embodiments of the present invention, 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. Any examples of operating parameters and/or environmental conditions are not exclusive of other parameters/conditions of the disclosed embodiments. Additionally, it should be understood that references to “one embodiment”, “an embodiment”, “certain embodiments,” or “other embodiments” of the present invention are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. Furthermore, reference to terms such as “above,” “below,” “upper”, “lower”, “side”, “front,” “back,” or other terms regarding orientation are made with reference to the illustrated embodiments and are not intended to be limiting or exclude other orientations.
Recitation of ranges of values herein are merely intended to serve as a shorthand method of referring individually to each separate value falling within range, unless otherwise indicated herein and each separate value is incorporated into specification as if it were individually recited herein. In at least one embodiment, use of a term, such as a set (for a set of items) or subset unless otherwise noted or contradicted by context, is understood to be nonempty collection including one or more members. Further, unless otherwise noted or contradicted by context, term subset of a corresponding set does not necessarily denote a proper subset of corresponding set, but subset and corresponding set may be equal.
Conjunctive language, such as phrases of form, at least one of A, B, and C, or at least one of A, B and C, unless specifically stated otherwise or otherwise clearly contradicted by context, is otherwise understood with context as used in general to present that an item, term, etc., may be either A or B or C, or any nonempty subset of set of A and B and C. In at least one embodiment of a set having three members, conjunctive phrases, such as at least one of A, B, and C and at least one of A, B and C refer to any of following sets: {A}, {B}, {C}, {A, B}, {A, C}, {B, C}, {A, B, C}. Thus, such conjunctive language is not generally intended to imply that certain embodiments require at least one of A, at least one of B and at least one of C each to be present. In addition, unless otherwise noted or contradicted by context, terms such as plurality, indicates a state of being plural (such as, a plurality of items indicates multiple items). In at least one embodiment, a number of items in a plurality is at least two but can be more when so indicated either explicitly or by context. Further, unless stated otherwise or otherwise clear from context, phrases such as based on means based at least in part on and not based solely on.
In at least one embodiment, even though the above discussion provides at least one embodiment having implementations of described techniques, other architectures may be used to implement described functionality, and are intended to be within scope of this disclosure. In addition, although specific responsibilities may be distributed to components and processes, they are defined above for purposes of discussion, and various functions and responsibilities might be distributed and divided in different ways, depending on circumstances.
In at least one embodiment, although subject matter has been described in language specific to structures and/or methods or processes, it is to be understood that subject matter claimed in appended claims is not limited to specific structures or methods described. Instead, specific structures or methods are disclosed as example forms of how a claim may be implemented.
From all the above, a person of ordinary skill would readily understand that the tool of the present disclosure provides numerous technical and commercial advantages and can be used in a variety of applications. Various embodiments may be combined or modified based in part on the present disclosure, which is readily understood to support such combination and modifications to achieve the benefits described above.
It should be appreciated that embodiments herein may utilize one or more values that may be experimentally determined or correlated to certain performance characteristics based on operating conditions under similar or different conditions. The present disclosure described herein, therefore, is well adapted to carry out the objects and attain the ends and advantages mentioned, as well as others inherent therein. While a presently preferred embodiment of the disclosure has been given for purposes of disclosure, numerous changes exist in the details of procedures for accomplishing the desired results. These and other similar modifications will readily suggest themselves to those skilled in the art and are intended to be encompassed within the spirit of the present disclosure disclosed herein and the scope of the appended claims.
This Non-Provisional Application claims the benefit of priority to U.S. Provisional Application No. 63/532,845, titled “TUBING HANGER RE-ENTRY TOOL,” filed Aug. 15, 2023, the entire contents of which is incorporated by reference herein for all intents and purposes.
| Number | Date | Country | |
|---|---|---|---|
| 63532845 | Aug 2023 | US |
