Patent Description:
A jack-up type drilling rig (as opposed to a floating rig) tends to be used in relatively shallow water, e.g. up to about <NUM> depth. The conventional arrangement is for an offshore hydrocarbon well to be associated with a platform above sea level; the wellhead (WH) is located on the platform and a riser connects between the subterranean well and the wellhead. This riser passes within the supporting structure (jacket) of the platform and is therefore well protected from accidental impact by surface vessels or debris. Drilling and completion operations are performed by a jack-up rig which comes alongside the platform and extends a cantilever section over the platform. Drilling and completion operations are performed using a rig tower and other equipment, including a blowout preventer (BOP), supported on the cantilever section of the jack-up rig.

More recently, operators are starting to use subsea well templates in place of platforms. In this case, the wellhead and blow out preventer are normally located on the seabed. In theory, a jack-up rig would be used to install a subsea WH and BOP and to perform drilling and completion operations, but most jack-up rigs are in fact not designed to deploy, install and retrieve a subsea BOP which is a very heavy and large piece of equipment. Therefore, a specially adapted jack-up has to be used for this purpose, with associated issues of cost and availability of a specialized jack-up.

For this reason, it can be desirable to perform drilling and completion operations on subsea wellheads with the BOP located on the jack-up since this avoids the need for a specialized jack-up rig. The applicant has found operations with the above configuration to be successful but desires to further enhance safety and efficiency.

The invention therefore aims to provide improved equipment and/or methodology for drilling and/or completion of a subsea well and wellhead using a jack up rig, when the BOP is located on the jack-up. <CIT> describes systems and methods to contain fluids discharged form a subsea well or at the surface by capping the well blowout with a pre-positioned capping device. The capping device includes at least one blind shear ram and is separate from a blowout preventer. Difference personnel offsite of a rig drilling the well may have access and control to operate the device.

The invention more particularly includes a process for drilling or completing a subsea wellbore with subsea wellhead from a jack-up rig as defined in claim <NUM>. In this way, an emergency cut off may be provided for use in the event that the high-pressure riser is compromised (e.g. because of a collision with a vessel). The ability to seal the well at the wellhead can also be convenient for other operations which would otherwise require a temporary plug to be installed, which is expensive in rig time.

Thus, the ram or valve may be used to close in the wellbore, or the ram or valve may close and seal around tubing or casing in the well. The ram or valve may be a shear and seal ram and wherein the process includes actuating the ram in the event of an emergency to shear drill pipe passing through the assembly and make a seal.

With the ram or valve closed, the riser may be removed in order to install subsea equipment.

The suspension head may be installed by the jack-up rig, since it has lower mass than a BOP. The suspension head may have a mass of between <NUM>,<NUM> and <NUM>,<NUM>, optionally between <NUM>,<NUM> and <NUM>,<NUM>, and may be installed over the side of the jack-up using an offshore rig crane on the rig.

A suspension head assembly for drilling or completing a well comprises: (a) a first connector for connecting the assembly to a wellhead; (b) a second connector for connecting the assembly to a riser; (c) at least one ram or valve for sealing a well when the assembly is connected to a wellhead. The ram or valve may be suitable for closing and sealing around tubing or casing, or it may be a shear and seal ram (SSR) for use in an emergency. Both types of ram may be provided, e.g. in a double ram block. The second connector may include a re-entry hub.

The second connector may take the form of a re-entry hub of the same type (profile and shape) as the wellhead. The high-pressure riser is deployed with a connector installed on it, which can connect into the re-entry hub of the suspension head in the same way it would connect with the re-entry hub of the wellhead.

The invention also provides a system for drilling or completing a subsea wellbore as defined in claim <NUM>.

Examples and various features and advantageous details thereof are explained more fully with reference to the exemplary, and therefore non-limiting, examples illustrated in the accompanying drawings and detailed in the following description. Descriptions of known starting materials and processes can be omitted so as not to unnecessarily obscure the disclosure in detail. It should be understood, however, that the detailed description and the specific examples, while indicating the preferred examples, are given by way of illustration only and not by way of limitation. Various substitutions, modifications, additions and/or rearrangements within the scope of the underlying inventive concept will become apparent to those skilled in the art from this disclosure.

As used herein, the terms "comprises," "comprising," "includes," "including," "has," "having" or any other variation thereof, are intended to cover a non exclusive inclusion. For example, a process, product, article, or apparatus that comprises a list of elements is not necessarily limited only those elements but can include other elements not expressly listed or inherent to such process, process, article, or apparatus.

The term substantially, as used herein, is defined to be essentially conforming to the particular dimension, shape or other word that substantially modifies, such that the component need not be exact. For example, substantially cylindrical means that the object resembles a cylinder, but can have one or more deviations from a true cylinder.

Additionally, any examples or illustrations given herein are not to be regarded in any way as restrictions on, limits to, or express definitions of, any term or terms with which they are utilized. Instead these examples or illustrations are to be regarded as being described with respect to one particular example and as illustrative only. Those of ordinary skill in the art will appreciate that any term or terms with which these examples or illustrations are utilized encompass other examples as well as implementations and adaptations thereof which can or cannot be given therewith or elsewhere in the specification and all such examples are intended to be included within the scope of that term or terms. Language designating such non-limiting examples and illustrations includes, but is not limited to: "for example," "for instance," "e.g.," "In some examples," and the like.

Although the terms first, second, etc. can be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms. These terms are only used to distinguish one element, component, region, layer or section from another. Thus, a first element, component, region, layer or section discussed below could be termed a second element, component, region, layer or section without departing from the teachings of the present inventive concept.

While preferred examples of the present inventive concept have been shown and described herein, it will be obvious to those skilled in the art that such examples are provided by way of example only. Numerous variations, changes, and substitutions will now occur to those skilled in the art without departing from the disclosure. It should be understood that various alternatives to the examples of the disclosure described herein can be employed in practicing the disclosure. It is intended that the following claims define the scope of the disclosure and that methods and structures within the scope of these claims and their equivalents be covered thereby.

As shown in <FIG>, a jack-up type drilling rig <NUM> comprises a platform <NUM> supported by legs <NUM> which pass through the sea surface <NUM> and rest on the seafloor <NUM>. A drilling rig tower <NUM> is located on the platform <NUM>. All of this is conventional.

Unusually for drilling and completion of a subsea well/wellhead, a blowout preventer <NUM> is located on the platform <NUM>, for the reasons explained above. Because the blow out preventer, or BOP, is located on the platform of the drilling rig rather than being mounted on the wellhead, a high-pressure riser <NUM> is required to connect the BOP <NUM> to the wellhead <NUM>. Depending on the operation being performed, tubing or casing or drill string, or combinations of those, represented by reference numeral <NUM> in <FIG>, passes down into the well through the wellhead <NUM>.

A suspension head <NUM> is mounted on the wellhead <NUM> and the high-pressure riser connected to the top of the suspension head <NUM>.

The conventional arrangement for a subsea wellhead, as stated above, is to have the BOP mounted directly onto the wellhead. A conventional marine riser then connects the BOP to the drilling platform. The BOP is controlled from the drilling rig, and includes the normal safety features allowing the well to be closed in the event of an emergency, e.g. due to the pressure from the formation unexpectedly or suddenly increasing. Because the BOP is located on the wellhead, the pressure in the riser need not be high.

In the arrangement with the BOP on the jack-up drilling rig, the normal arrangement on the seafloor is shown schematically in <FIG>. The high-pressure riser <NUM> is connected to the wellhead <NUM> via a riser connector <NUM>. Casing, tubing, drill string or a combination of these, is shown at <NUM>. Although this arrangement works well and avoids the need to use a specialized jack-up rig, there are some concerns as set out below.

In the arrangement shown in <FIG>, the BOP on the rig provides the same safety functions which are normally performed by a subsurface BOP. However, in this arrangement, the riser <NUM> is exposed to high pressures from the formation. The use of this high-pressure riser represents a potential increased risk because the riser passes through the surface <NUM> of the sea (the splash zone) and therefore is exposed to potential risks from collisions with surface vessels, foreign objects (e.g. a barge), or from extreme weather conditions.

<FIG> shows in schematic form a subsea installation in accordance with the invention. The wellhead <NUM>, tubing, etc., <NUM> and high-pressure riser <NUM> are shown, with the high-pressure riser <NUM> connected into the assembly via a riser connector <NUM>. However, a suspension head assembly <NUM> is provided between the riser connector <NUM> and wellhead <NUM>.

The suspension head assembly <NUM> comprises a heavy duty H4-profile connector <NUM> connected to the wellhead <NUM>, a re-entry hub <NUM> connected to the riser connector <NUM>, and a double ram block <NUM>. The re-entry hub <NUM> includes a TH orientation pin <NUM>. The functions of all these components, each of which is in itself a well-known piece of equipment, will be explained below.

The double ram block <NUM> comprises a shear/seal ram (or SSR) <NUM> which is designed, when actuated, to cut through drill pipe passing through the block <NUM> and then form a seal. The shear/seal ram <NUM> is obviously for use in emergencies, e.g. if formation pressure cannot be contained by the normal means and presents a danger. The block <NUM> also contains a casing ram <NUM> which is designed to seal around <NUM>¾" casing.

A side inlet <NUM> is provided below the SSR <NUM>, which communicates with the well. Side inlet fail safe close valves <NUM> control the opening or closing of the side inlet. By closing the casing ram <NUM> and opening side inlet valves <NUM> below the SSR, fluid may be delivered to the well by an alternative route. This facilitates a more efficient installation and testing of the completion string. In addition, this allows the use of the tubing hanger running tool secondary release function. In the absence of the suspension head, a temporary plug would have to be installed requiring a day or more's rig time, with associated expense.

The re-entry hub <NUM> and orientation pin <NUM> are used when a tubing hanger is to be landed on the wellhead; the pin <NUM> is manipulated by an ROV to rotate the Tubing Hanger into the correct orientation.

The suspension head <NUM> also includes a control panel <NUM> for actuating the rams <NUM>, <NUM> and connectors, and for actuating failsafe close valves <NUM> for the side inlet <NUM>. The controls on control panel <NUM> may be actuated by a remotely operated subsea vehicle (not shown).

The suspension head assembly comprises some of the components normally found in a BOP (e.g. the rams), but is a considerably smaller and lighter piece of equipment than a BOP. A BOP includes, for example, several ram configurations, control pods, and an accumulator bank for enhancing the delivery of hydraulic power. Together all this sums up to the majority of the mass of a BOP. A BOP may have a mass of between <NUM> and <NUM> metric tonnes (<NUM>,<NUM> to <NUM>,<NUM>) whereas a suspension head in accordance with the invention may have a mass of about <NUM> metric tonnes (<NUM>,<NUM>). For this reason, a standard jack-up rig will normally have the lifting capacity to install a suspension head according to the invention, whilst the standard jack-up would be unable to install a BOP.

Claim 1:
A process for drilling or completing a subsea wellbore with subsea wellhead (<NUM>) from a jack-up rig, the process comprising:
a) installing a blow-out preventer on the jack-up rig;
b) installing a riser (<NUM>) between the blow-out preventer and the subsea wellhead (<NUM>);
c) connecting a suspension head assembly (<NUM>) between the riser and wellhead (<NUM>), wherein the assembly (<NUM>) includes at least one ram or valve (<NUM>, <NUM>) for sealing the well;
characterised in that:
the assembly (<NUM>) comprises a side inlet (<NUM>) below the at least one ram or valve (<NUM>, <NUM>) which communicates with the well, and side inlet fail safe close valves (<NUM>) for controlling the opening or closing of the side inlet (<NUM>);
wherein the method comprises:
closing the ram or valve (<NUM>, <NUM>) around the tubing or casing (<NUM>) in the well to close the wellbore, and opening side inlet valves (<NUM>) to deliver fluid to the well:
removing the riser (<NUM>) whilst the ram or valve (<NUM>, <NUM>) is closed; and
installing subsea equipment.