Patent Description:
To meet demand for natural resources, companies often invest substantial amounts of time and money in searching for and extracting oil, natural gas, and other subterranean resources from the earth. Once a desired subterranean resource is discovered, drilling and production systems are employed to access and extract the resource. These systems may be located onshore or offshore depending on the location of a desired resource. Such systems generally include a wellhead assembly through which the resource is extracted. These wellhead assemblies may include a wide variety of components, e.g. casings, hangers, valves, fluid conduits, that control drilling and/or extraction operations. In some drilling and production systems, casing hangers and other types of tubing hangers may be used to suspend strings (e.g. piping for various flows in and out of the well). Such hangers may be disposed within a housing of a wellhead which supports both the hanger and the string. The hanger may be secured to the wellhead via a locking or mounting mechanism activated by a running tool. <CIT> describes a running tool with an inner sleeve and an outer sleeve. The tool can be used to lower a casing hanger until it rests on as shoulder provided within a housing. Rotation of the outer sleeve is used to rotate a ring threaded on the casing hanger which forces a locking ring to engage the housing.

In general, a system and methodology are provided for utilizing a running tool system with respect to a tubing hanger deployed at a wellhead. One aspect of this invention provides a system, comprising a running tool and hanger system, comprising:.

Another aspect of this invention provides a method, comprising coupling a running tool to a hanger, using the running tool to move the hanger in an axial direction down into a wellhead, and rotating an outer sleeve of the running tool relative to an inner sleeve of the running tool to drive an adjustable landing ring into engagement with a load ring;
wherein a support ring is releasably coupled to the adjustable landing ring and the load ring is supported by the support ring , and the method comprises temporarily gripping the hanger in the wellhead while rotating the outer sleeve shifts the load ring to a profile formed along an interior surface of the wellhead.

Certain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of the invention as defined by the claims.

Embodiments described herein are directed to a running tool system which may be used to expedite well operations, e.g. drilling operations. As explained in greater detail below, the running tool system enables a running tool to both lower and set a hanger without a separate tool, e.g. without a slipshot sleeve, sliding over the running tool and without running multiple tools. The running tool system described herein may thus be used to run, e.g. deploy, the hanger and/or tubing into a wellbore and to secure, e.g. lock, the hanger within the wellhead in a single trip.

Referring generally to <FIG>, a schematic illustration is provided of a mineral extraction system <NUM>. The mineral extraction system <NUM> is configured to extract various natural resources, e.g. hydrocarbons, from a mineral deposit <NUM>. For example, the mineral extraction system <NUM> may be used to extract oil and/or natural gas from a subterranean reservoir forming mineral deposit <NUM>. Depending on where the natural resource is located, the mineral extraction system <NUM> may be a surface system, e.g. landbased system, or a subsea system. The illustrated mineral extraction system <NUM> comprises a wellhead <NUM> which may be placed in communication with the mineral deposit/reservoir <NUM> via a well <NUM> having a wellbore <NUM>. The wellbore <NUM> extends from the mineral deposit/reservoir <NUM> to a hub <NUM> of the wellhead <NUM> located at or near the surface.

The illustrated wellhead hub <NUM>, which may be a large diameter hub, acts as a junction between the well <NUM> and the equipment located above the well <NUM>. The wellhead hub <NUM> may include a complementary connector, e.g. a collet connector, to facilitate connections with the surface equipment. Additionally, the wellhead hub <NUM> may be constructed to support various strings of casing/tubing that extend into the wellbore <NUM> and, in some cases, extend down into the mineral deposit <NUM>.

The wellhead <NUM> generally comprises a series of devices and components which control and regulate activities and conditions associated with the well <NUM>. For example, the wellhead <NUM> may provide for routing the flow of minerals, e.g. oil and/or gas, produced from the mineral deposit <NUM> in wellbore <NUM>. Additionally, the wellhead <NUM> may provide for regulating pressure in the well <NUM> and/or for the injection of chemicals downhole into the wellbore <NUM>. In the illustrated embodiment, the wellhead <NUM> includes a housing/casing spool <NUM>, e.g. a tubular housing, and a tubing spool <NUM>. A hanger <NUM>, e.g. a tubing hanger or a casing hanger, may be deployed and set in the casing spool/housing <NUM>. The wellhead <NUM> also may comprise a blowout preventer (BOP) <NUM>.

In operation, the wellhead <NUM> enables completion and workover procedures such as tool insertion into well <NUM> for installation and removal of various components, e.g. hangers, shoulders, and/or other components. Furthermore, oil, gas, and/or other minerals extracted from the well <NUM> may be regulated and routed via the wellhead <NUM>. According to one example, the blowout preventer <NUM> may include a variety of valves, fittings, and control features to prevent oil, gas, or other fluid from exiting the well <NUM> in the event of an unintentional release of pressure or an overpressure condition.

In the illustrated example, the casing spool <NUM> defines a bore <NUM>, e.g. a casing spool bore, which enables fluid communication between the wellhead <NUM> and the well <NUM>. Thus, the bore <NUM> may provide access to the wellbore <NUM> during various completion and workover procedures including deploying tools or components within the casing spool <NUM>. For example, the illustrated embodiment of mineral extraction system <NUM> comprises a running tool <NUM> suspended from a string <NUM> to form a running tool system <NUM>. The running tool <NUM> may be moved axially to position hanger <NUM> and also rotationally to apply torque for installing the hanger <NUM> in the casing spool <NUM>.

In contrast, a conventional installation of a hanger involves both a running tool and a separate sleeve, e.g. a slipshot sleeve, which slides over the running tool. With conventional systems, the running tool lowers the hanger into the wellhead while the separate sleeve slides over the running tool to contact and set the hanger. As explained in greater detail below, however, the running tool system <NUM>, illustrated in <FIG> and described herein, enables the running tool <NUM> to both lower and set the hanger <NUM> without a separate tool sliding over the running tool <NUM> and without running multiple tools.

Referring generally to <FIG>, a cross-sectional illustration of an example of running tool system <NUM> is illustrated as coupled with hanger <NUM>. The running tool system <NUM> is employed for lowering and setting the hanger <NUM> in the wellhead <NUM>, e.g. in the casing spool <NUM>. As illustrated, the running tool <NUM> comprises an inner sleeve <NUM> and an outer sleeve <NUM>. The inner sleeve <NUM> is coupled to and supports the hanger <NUM> while the outer sleeve <NUM> is coupled to an adjustable landing ring <NUM>. By way of example, the inner sleeve <NUM> (and thus running tool <NUM>) may be releasably coupled to hanger <NUM> via a coupling mechanism <NUM>, e.g. a threaded engagement region, a collet mechanism, or another suitable coupling mechanism. In operation, the string <NUM> is used to lower the running tool <NUM> which, in turn, lowers the hanger <NUM> in the direction indicated by arrow <NUM>. The hanger <NUM> may be lowered until the hanger <NUM> aligns with a hanger suspension system <NUM>. The hanger suspension system <NUM> may comprise casing slips <NUM> which are coupled to corresponding pistons <NUM>.

During a hanger suspension operation, the pistons <NUM> are driven radially inward in the direction indicated by arrows <NUM>. The pistons <NUM> may be shifted via an actuator <NUM> until the casing slips <NUM> are coupled with and suspend the hanger <NUM> within the casing spool <NUM>. The casing slips <NUM> may thus be used to grip the hanger <NUM> until it is more permanently secured in the wellhead <NUM> as described in greater detail below. The actuator <NUM> may be a hydraulic actuator, electric actuator, manual actuator, combinations of actuators, or another type of suitable actuator or actuators. In some embodiments, the actuator <NUM> may be in the form of a hydraulic actuator which receives hydraulic actuating fluid via ports <NUM>.

The running tool <NUM> may be used to deploy the hanger <NUM> into the casing spool <NUM>. However, after coupling the hanger <NUM> with the casing slips <NUM>, the running tool <NUM> may be relaxed, e.g. tension on string <NUM> may be released or reduced. At this stage, the running tool <NUM> may be rotated to energize the adjustable landing ring <NUM>. By releasing tension on the running tool <NUM>, the running tool system <NUM> may reduce strain between hanger <NUM> and the adjustable landing ring <NUM>. This, in turn, is able to facilitate coupling of the hanger <NUM> to the casing spool <NUM>, e.g. via rotation of the adjustable landing ring <NUM>.

In operation, the outer sleeve <NUM> is releasably coupled with and rotates the adjustable landing ring <NUM> to cause engagement of a split load ring <NUM> to the casing spool <NUM>. It should be noted that once casing slips <NUM> are engaged with, e.g. biting into, hanger <NUM> an upper joint <NUM> of the running tool <NUM> may be lowered relative to inner sleeve <NUM> to depress a dog <NUM>, as illustrated in <FIG>, such that the dog <NUM> is released from the corresponding recess <NUM>. Release of dog <NUM> effectively releases the outer sleeve <NUM> from the inner sleeve <NUM> and this allows the upper joint <NUM> and the outer sleeve <NUM> to freely rotate together relative to hanger <NUM>. As the upper joint <NUM> and outer sleeve <NUM> are rotated in direction <NUM>, they are able to wind down landing ring <NUM> so as to shift split load ring <NUM> for engagement with casing spool <NUM>.

For example, rotation of the outer sleeve <NUM> via running tool <NUM> in direction <NUM> causes the outer sleeve <NUM> to rotate the adjustable landing ring <NUM> about the hanger <NUM>. In the example illustrated, the adjustable landing ring <NUM> is threadably engaged with the hanger <NUM> via threads <NUM>. Thus, rotation of the adjustable landing ring <NUM> with respect to hanger <NUM> causes it to move in direction <NUM>.

As the adjustable landing ring <NUM> moves axially in direction <NUM> (due to rotation by sleeve <NUM>), the adjustable landing ring <NUM> drives a contact or support ring <NUM> in direction <NUM>. In some embodiments, the support ring <NUM> may be releasably coupled with adjustable landing ring <NUM> via a shear member <NUM>, e.g. a shear pin. The contact or support ring <NUM> supports the split load ring <NUM> which is configured to engage a profile, e.g. a groove, <NUM> located on an interior surface of the casing spool <NUM> or other suitable portion of wellhead <NUM>. As the outer sleeve <NUM> continues to rotate the landing ring <NUM>, the contactor support ring <NUM> continues to move in direction <NUM> until it engages a plug <NUM>.

The plug <NUM> stops further axial movement of the support ring <NUM> in direction <NUM> so as to axially align the split load ring <NUM> with the groove <NUM>. As the running tool <NUM> continues to rotate, the rotating outer sleeve <NUM> causes the adjustable landing ring <NUM> to shear through the shear pin <NUM> which couples support ring <NUM> to the adjustable landing ring <NUM>. The adjustable landing ring <NUM> is then able to continue rotating independently of the support ring <NUM>. As the adjustable landing ring <NUM> continues to be rotated, the adjustable landing ring <NUM> slides under the split load ring <NUM> and drives the split load ring <NUM> radially outward in the direction represented by arrows <NUM>. As the split load ring <NUM> moves radially outward in direction <NUM>, the split load ring <NUM> engages the groove <NUM>, thus coupling the hanger <NUM> to the casing spool <NUM> (see <FIG>).

Because upper joint <NUM> and outer sleeve <NUM> are coupled together and rotate together, the outer sleeve <NUM> may be coupled with adjustable landing ring <NUM> via a castellation <NUM> (or other suitable structure) as further illustrated in <FIG>. In this example, the outer sleeve <NUM> comprises a castellation member <NUM> received in a corresponding recess <NUM> formed in, for example, an upper edge of adjustable landing ring <NUM>. It should be noted, the number of castellation members <NUM> and recesses <NUM> may vary.

As illustrated, the castellation member <NUM> comprises an abutment edge <NUM>, e.g. a right angle edge, which engages a corresponding abutment edge <NUM> in recess <NUM> of adjustable landing ring <NUM>. The abutment edge <NUM> and corresponding abutment edge <NUM> allow the outer sleeve <NUM> to force rotation of adjustable landing ring <NUM> in a desired direction, e.g. direction <NUM>. However, the castellation member <NUM> also comprises a sloped edge <NUM>, e.g. a <NUM>° angle edge, opposite abutment edge <NUM>. The sloped edge <NUM> is oriented to engage a corresponding sloped edge <NUM> disposed appropriately in recess <NUM> of adjustable landing ring <NUM>.

Thus, when upper joint <NUM> is rotated together with outer sleeve <NUM> in the opposite direction, e.g. direction <NUM>, the outer sleeve <NUM> will not rotate adjustable landing ring <NUM> due to the engagement of sloped edge <NUM> and corresponding sloped edge <NUM>. As the upper joint <NUM> and outer sleeve <NUM> are rotated in direction <NUM>, the sloped edges <NUM>, <NUM> cause the outer sleeve <NUM> to slide up and out of recess <NUM> to enable rotation of outer sleeve <NUM> with respect to adjustable landing ring <NUM>. By way of example, the upper joint <NUM> and outer sleeve <NUM> may be rotated in direction <NUM> to release coupling mechanism <NUM> during, for example, retrieval of casing hanger running tool <NUM> from casing hanger <NUM>. In other words, the upper joint <NUM> and outer sleeve <NUM> may be rotated in direction <NUM> freely so as to fully unthread the casing hanger running tool <NUM> from the hanger <NUM> (at least in embodiments using a threaded engagement between tool <NUM> and hanger <NUM>). This allows retrieval of the running tool <NUM>, as illustrated in <FIG>.

In <FIG>, a cross-sectional view is provided which shows hanger <NUM> coupled to the casing spool <NUM> after removal of running tool <NUM>. As illustrated, the split load ring <NUM> rests within the groove <NUM>. The adjustable landing ring <NUM> blocks retraction of the split load ring <NUM> out of the groove <NUM> in direction <NUM>. It should be noted that once the hanger <NUM> is coupled with the casing spool <NUM>, the actuator <NUM> may be operated to retract the pistons <NUM>, thus enabling disengagement of the casing slips <NUM> from the hanger <NUM>. Likewise, the running tool <NUM> may be disengaged from the hanger <NUM> as described above. After the running tool <NUM> is disengaged from the hanger <NUM> and removed, another tool may be used to run and install components, e.g. a seal system <NUM> between the casing spool <NUM> and the hanger <NUM>.

The running tool <NUM> may be mounted on a variety of strings <NUM> and may comprise a variety of features for coupling with and actuating components of hanger <NUM> and/or other tools. Similarly, the hanger <NUM> may be used for hanging a variety of tubular members and may have a variety of features to accommodate setting and use of the hanger. The hanger <NUM> also may be used in many types of wellheads <NUM> having various components and features. The sizes and configurations of components and features also may be selected according to the structural parameters and operating parameters of a given downhole operation.

Claim 1:
A system, comprising:
a running tool and hanger system (<NUM>), comprising:
a running tool (<NUM>) configured for coupling with a hanger (<NUM>), the running tool (<NUM>) having: a first sleeve (<NUM>) configured to couple to and move the hanger (<NUM>) in an axial direction; and
a second sleeve (<NUM>) which is an outer sleeve relative to the first sleeve (<NUM>) and is configured to couple to an adjustable landing ring (<NUM>) surrounding the hanger (<NUM>), the second sleeve (<NUM>) being configured to rotate the adjustable landing ring (<NUM>) to lock the hanger (<NUM>) in position; and
a hanger suspension system (<NUM>) configured to couple to and suspend the hanger (<NUM>) in the wellhead as the running tool (<NUM>) rotates and adjusts the position of the adjustable landing ring (<NUM>);
wherein the system further comprises:
a support ring (<NUM>) releasably coupled to the adjustable landing ring (<NUM>) and a load ring (<NUM>) supported by the support ring (<NUM>), and
the system is configured for rotation of the adjustable landing ring (<NUM>) by the second sleeve to force the load ring (<NUM>) into engagement with an interior surface of the wellhead.