MX2013014050A - Subsea containment cap adapters. - Google Patents

Abstract

A method for controlling hydrocarbons flowing from a subsea structure comprises lowering an adapter from the surface to a subsea structure. The adapter has a through bore extending between an upper connector having a first connector profile and a lower connector having a second connector profile that is different than the first connector profile. In addition, the method comprises coupling the lower connector of the adapter to the subsea structure. Further, the method comprises lowering a containment cap from the surface to the adapter. Still further, the method comprises coupling the containment cap to the upper connector of the adapter.

Description

SUBMARINE CONTAINMENT CAP ADAPTERS Cross Reference to Related Patent Applications The present patent application claims priority of the US provisional patent application Minute No. 61 / 500,679 which was filed on June 24, 2011, and entitled "Underwater Container Cap Adapter," which is incorporated herein in its entirety. as reference. The present patent application also claims priority from the US provisional patent application Minute No. 61 / 498,269 which was filed on June 17, 2011, and entitled "Containment Cap Suitable for Air Cargo to Contain a Submarine Well," which is it is incorporated herein by reference in its entirety.

Affidavit Regarding Research and Development Sponsored by the Federal Government of the United States It does not correspond.

Background of the Invention Field of the Invention The invention relates in general to systems and methods for containing an underwater well that is discharging hydrocarbons. More specifically, the invention relates to systems and methods for plugging an underwater well using a cover containment and attaching the cover to any one of at least four different underwater structures: the wellhead, the blowout preventer (BOP), the bundle mandrel of the lower sealant pipeline extension, or the flexible joint, or the gasket Flexible of the pipeline extension. Still more specifically, the invention relates to an adapter or transition spool that allows the same containment cap to engage numerous subsea structures configured in a different manner.

Technology Background In marine drilling operations, a blowout preventer (BOP) is installed over the mouth of the well at the bottom of the sea and an extension pack of lower casing pipe (LMRP) is mounted to the blowout preventer. In addition, an extension of drilling casing extends from a flexible joint at the upper end of the LMRP to a ship or derrick on the sea surface. Then a drill string is suspended from the tower through the drill pipe extension, the LMRP and the BOP into the well. A choke line and a death line are also suspended from the tower and attached to the BOP, usually as part of the assembly of casing pipe extensions.

During drilling operations, the drilling liquid, or slurry, is supplied through the drill string and returns through a ring between the drill string and the casing covering the well. In the case of a rapid inflow of formation liquid into the ring, commonly referred to as a "kick", the BOP and / or the LMRP can be operated to seal the ring and control the well. Specifically, BOPs and LMRPs comprise closure members capable of sealing and closing the well to prevent the release of gas or liquids from the well. Therefore, the BOP and the LMRP are used for devices that close, isolate and seal the well. However, drilling mud can be supplied through the drill string, pushing the liquid from the spinner through the throttling line or death line to protect the well equipment disposed above the BOP and the LMRP of the pressures associated with the formation liquid. Assuming that the structural integrity of the well has not been compromised, drilling operations can be resumed. However, if drilling operations can not be resumed, cement or a denser drilling mud can be supplied into the well to kill the well.

In the event that the well is not sealed, a burst may occur. The explosion may damage the equipment and / or submarine connections between the underwater equipment. This can be especially problematic if it results in the discharge of hydrocarbons within the surrounding seawater. Also, challenge rectification remotely since the discharge may be hundreds or thousands of meters below the surface of the sea.

In the event that an underwater explosion results in the discharge of hydrocarbons in the surrounding area, it is important to plug and / or close the well as soon as possible to minimize the volume of discharged hydrocarbons. One of the possible approaches to plugging and closing an underwater well is to lower a containment cover and attach it to the upper end of the equipment stack that is connected to the well. However, it can not be predicted in advance where the discharge may originate within the equipment stack, in which way it may be necessary to reconfigure the equipment to plug the well, or on which equipment or subsea structure the containment cover will be supported to better control the well. In addition, various BOP manufacturers, packages of lower casing extensions, manholes and other subsea structures have not standardized the dimensions and configurations of their products. That is, for example, that the profile of a wellhead connector of a first manufacturer may differ from the profile of the connector provided by a second manufacturer. Similarly, as another example, the connections that are on top of a lower marine pipeline extension package from a first manufacturer may differ in their design and configuration. that of another manufacturer. A containment cap that has a connector with a specific connector profile can not be attached directly to structures and equipment that have non-correspondingly configured connections. It would be a challenge to redesign and / or configure the cap stack connector to make it compatible with an equipment component in an underwater well from which hydrocarbons are being discharged and such redesign or readjustment of the containment cap may retard the containment of the well. and allow the download to continue in the meantime.

Accordingly, there is still a need in the art for systems and methods to plug an underwater well. Such systems and methods would be welcome if they offered the potential to plug an underwater well that is discharging hydrocarbon liquids. It would be particularly welcome by the industry a cap pile, a system and a method to contain underwater wells that use a single containment cap that has a uniform design, that is capable of being deployed and coupled to underwater components with a different configuration that they have numerous coupling configurations.

Brief Extract of the Invention These and other art needs are faced in one of the embodiments by a method for controlling the hydrocarbons flowing from an underwater structure. In one embodiment, the method comprises lowering an adapter from the surface to an underwater structure. The adapter has a through hole that extends between an upper connector having a first connector profile and a lower connector having a second connector profile that is different from the first connector profile. In addition, the method comprises coupling the lower connector of the adapter to the underwater structure. In addition, the method comprises lowering a containment cap from the surface to the adapter. Moreover, the method comprises coupling the containment cap to the upper connector of the adapter.

These and other art needs are confronted in another embodiment by a method for plugging an underwater well. In one embodiment, the method comprises choosing from an inventory of adapters a selected adapter. The selected adapter has a lower connector with a lower connector profile configured to couple it with a connector on an underwater structure and an upper connector with a profile of the upper connector that is different from the profile of the lower connector. In addition, the method comprises the lower connector of the selected adapter to the subsea structure.

These and other art needs are confronted in another embodiment by a method for plugging an underwater well. In one embodiment, the method comprises maintaining an inventory comprising a plurality of adapters. Each one of the plurality of adapters having an upper connector with a profile of the upper connector and a lower connector with a profile of the lower connector that differs from the profile of the upper connector and that also differs from the profile of the lower connector of at least some of the other adapters of plurality In addition, the method comprises identifying the connector profile of a submarine connector on an underwater structure in a well that is discharging hydrocarbons into the sea water surrounding it. In addition, the method comprises selecting from the inventory a select adapter with the profile of the lower connector that is configured to mate with the submarine connector.

These and other needs of the art are faced in another embodiment by an adapter for attaching a containment cap to an underwater structure. In one embodiment, the adapter comprises a first part having a central axis, a first end, a second end opposite the first end and a through bore extending from the first end axially from the first end to the second end. The first end comprises a first connector having a first connector profile. Further the adapter comprises a second part having a central axis, a first end, a second end opposite the first end, and a through bore extending axially from the first end to the second end. The second end comprises a second connector having a second connector profile that is different from the second connector profile.

These and other art needs are confronted in another embodiment by an apparatus for controlling an underwater well. In one embodiment, the apparatus comprises a containment cap having a through hole and a valve adapted to close and prevent the liquid from running through a through hole, and further comprising a connector at the lower end of the containment cap which has a profile of the first connector. In addition, the apparatus comprises an adapter. The adapter includes an upper end and a lower end and a through bore extending therethrough. The adapter also includes a first connector at the upper end coupled and meshed in sealing manner with the connector of the containment cap. In addition, the adapter includes a second connector at the lower end adapted to engage and engage sealingly with a connector on a submarine structure different from that of the containment cap. The second connector of the adapter has a profile of the second connector that is different from the profile of the first connector.

Therefore, the embodiments described herein comprise a combination of features and advantages intended to face various drawbacks associated with certain prior devices, systems and methods. The various elements and features described above, as well as others, will be readily apparent to those skilled in the art upon reading the following detailed description and with reference to the accompanying drawings.

Brief Description of the Drawings For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings in which: Figure 1 is a schematic view of an embodiment of a marine drilling system.

Figure 2 is an enlarged view of the flexible joint of the liner pipe extension of the lower liner pipe extension package of Figure 1.

Figure 3 is a top view of the flange of the liner pipe extension adapter of Figure 2.

Figure 4 is a schematic view of the marine drilling system of Figure 1 damaged by an underwater explosion.

Figure 5 is a perspective view of an embodiment of a containment cap suitable for air cargo to contain the well of Figure 4.

Figure 6 is a cross-sectional side view of the containment cap of Figure 5.

Figure 7 is a perspective view of the lower assembly of Figure 5.

Figure 8 is a side view of the lower assembly of Figure 5.

Figure 9 is a top view of the lower assembly of Figure 5.

Figure 10 is a schematic view of the lower assembly of Figure 5.

Figure 11 is a perspective view of the upper assembly of figure 5.

Figure 12 is a side view of the upper assembly of Figure 5.

Figure 13 is a cross-sectional side view of the upper assembly of Figure 5.

Figure 14 is a schematic view of the upper assembly of Figure 5.

Figure 15 is a perspective view of the death-countercurrent assembly of Figure 5.

Figure 16 is a side view of the death-countercurrent assembly of Figure 5.

Figure 17 is a perspective view of the lower assembly of Figure 5 configured for underwater deployment.

Figure 18 is a mounting view showing the lower assembly of Figure 5, the tool in operation of Figure 7 and a pair of adapters for deploying the subsea bottom assembly.

Figure 19 is a perspective view of the upper assembly of Figure 5 configured for underwater deployment.

Figures 20A-20L are consecutive schematic views of the underwater display and the installation of the containment cover of Figure 5 directly in the BOP of Figure 4.

Figure 21 is a schematic view of the containment cap of Figure 5 directly in the mouth of the well of the Figure.

Figure 22 is a side view of an embodiment of a transition spool for attaching the containment cap of Figure 5 to the flexible joint of Figure 4.

Figure 23 is a perspective view of an embodiment of a system for adjusting the angular orientation of the casing extension adapter of Figure 2.

Figure 24 is a top view of the system of Figure 23.

Figure 25 is a perspective view of the base members of Figure 23 mounted to the base of the flexible joint of Figure 2.

Figure 26 is a perspective view of an embodiment of a system for adjusting the angular orientation of the casing extension adapter of Figure 2.

Figure 27 is a perspective view of a hydraulic cylinder assembly of Figure 26.

Figure 28 is a perspective view of an embodiment of a group of wedge members for locking the angular orientation of the casing extension adapter of Figure 2.

Figure 29 is a top view of the group of wedge members of Figure 28.

Figures 30A-30P are consecutive schematic views of the underwater deployment and installation of the containment cover of Figure 5 on the flexible joint of Figure 4.

Figure 31 is a side cross-sectional view of one embodiment of a containment cap suitable for air cargo, modular to contain the well of the Figure.

Figure 32 is a schematic view of an embodiment of a method for deploying the containment cap of Figure 5.

Figure 33 is a schematic view showing various transition spools used to couple the containment cover of Figure 5 or Figure 31 to a plurality of the flexible joint of the coating pipe extension having different connector profiles.

Figure 34 is a front view of an embodiment of a transitional spool according to the principles described herein.

Figure 35 is an exploded, perspective view of the transition spool of Figure 34.

Figures 36A-36N are exploded, front views of embodiments of the transition spools that include lower parts that have different connector profiles to accommodate different profiles of support site connectors.

Figure 37 is a schematic representation of an inventory, including the modular components of the containment cap and a plurality of transition spools for coupling the cap to various underwater components; Y Figure 38 is a schematic representation of another inventory, including modular components of the containment cap and the components of the transition reels that are ready to be coupled to form the finished transition spools before shipment.

Detailed Description of the Preferred Embodiments The following discussion refers to various embodiments of the invention. While one or more of these embodiments may be preferred, it should not be construed or otherwise used that the embodiments disclosed herein limit the scope of the invention, including the claims. Furthermore, an expert in the art will understand that the following description has a broad application and it is understood that the discussion of all the Embodiments is only one example of that embodiment, and it is not desired to suggest in any way that the scope of the invention, which includes the claims, is limited to that embodiment.

Certain terms are used throughout the following description and the claims and claims to refer to particular elements or components. As one skilled in the art will appreciate, different people can refer to some elements or components with different names. This document does not want to distinguish between components or elements that differ in the name but not in the function. The figures of drawings are not necessarily drawn in scale. Certain elements and components of the present may be shown exaggerated in scale or in a somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness.

In the following discussion and in the claims, the terms "including" and "comprising" are used in an open form and therefore must be interpreted to mean "including, but not limited to ...". In addition, the term "coupling" or "coupling" is understood to mean an indirect or direct connection. Therefore, if a first component is coupled to a second component, that connection can be through a direct gear between the two components, or through an indirect connection through other devices, components and / or intermediate connections. Furthermore, as used herein, the terms "axial" and "axially" generally mean along or parallel to a given axis (e.g., a central axis of a body or a part), while the terms " radial "and" radially "generally mean perpendicular to the given axis. For example, an axial distance refers to a distance measured along or parallel to the given axis, and a radial distance means a distance measured perpendicular to the given axis.

Referring now to Figure 1, there is shown an embodiment of a marine system 100 for drilling and / or producing a well 101. In this embodiment, the system 100 includes a sea platform 110 on the surface of the sea 102, a burst preventer. submarine (BOP) 120 mounted at the mouth of the well 130 at the bottom of the sea 103 and a pack of prolongation of lower marine casing (LMRP) 140 mounted to the BOP 120. The platform 110 is equipped with a derrick 111 that Holds a winch (not shown). An extension of drilling casing 115 extends from platform 110 to LMRP 140. In general, casing extension 115 is a large diameter pipe that connects LMRP 140 to floating platform 110. During the operations of perforation, the extension of casing 115 carries mud returns to the platform 110. The casing 131 extends from the mouth of the well 130 inside underground pit 101.

Downhole operations are carried out with a tubular chain 116 (for example, the drill string, the production pipeline chain, coiled tubing, etc.) which is supported by the derrick 111 and extends from the platform 110 through the extension of casing 115, the LMRP 140, the BOP 120 and into the well with casing 101. A downhole tool 117 is connected to the lower end of the tubular chain 116. In general, Downhole tool 117 may comprise any downhole tool for drilling, evaluating and / or producing well 101 which includes, but is not limited to, drill bits, seals, test equipment, drill guns and the like. During operations at the bottom of the well, the chain 116 and therefore the tool 117 coupled thereto can be moved axially, radially and / or rotationally in relation to the extension of casing 115, the LMRP 140, the BOP 120 and the casing 131.

The BOP 120 and the LMRP 140 are configured to controllably seal the well 101 and contain hydrocarbon liquids therein. Specifically, the BOP 120 has a central or longitudinal axis 125 and includes a body 123 with an upper end 123a secured in removable form to the LMRP 140, one end bottom 123b secured releasably to the well bore 130 and a main bore 124 extending axially between the upper and lower ends 123a, b. The main bore 124 is aligned coaxially with the well 101, thereby allowing fluid communication between the well 101 and the main bore 124. In this embodiment the BOP 120 is coupled to the LMRP 140 and the borehole 130 with hydraulically operated mechanical borehole type connections 150. In general, connections 150 may comprise any mechanical connection of the appropriate removable wellhead such as the available H-4® underwater profile system. at VetcoGray, Inc. of Houston, Texas, the underwater profile system of DWHC available from Cameron International Corporation of Houston, Texas and the underwater HC profile system available from FMC Technologies of Houston, Texas. Typically, such mechanical connections of the wellhead type (e.g., connections 150) comprise an upward facing or "plug" male connector, marked with the reference number 150a herein, which is received and engaged. in removable form to a female connector or receptacle that engages with it that faces downwards, complementary, marked with the reference number 150b herein. In addition, the BOP 120 includes a plurality of axially stacked groups of opposed rams: a group of opposed blind cutting rams or blades 127 for cutting the tubular chain 116 and sealing the well 101 to the extension of the casing 115 and two. groups of opposing pipe rams 128, 129 to mesh with the chain 116 and seal the ring around the tubular chain 116. In other embodiments, the BOP (eg, 120) may also include one or more groups of opposed blind rams for sealing the well when no chain (eg, chain 116) or tubular extends through the main bore of the BOP (eg, main bore 124). Each of the rams groups 127, 128, 129 is equipped with sealing members that mesh to prohibit the current through the ring around the chain 116 and / or the main bore 124 when the rams 127, 128, 129 They are closed.

The opposing rams 127, 128, 129 are disposed in cavities that intersect the main bore 124 and hold the rams 127, 128, 129 as they move in and out of the main bore 124. Each of the rams groups 127, 128, 129 is driven and transited between an open position and a closed position. In the open positions, the rams 127, 128, 129 are withdrawn radially from the main bore 124 and do not interfere with the tubular chain 116 or other hardware that can extend through the main bore 124. However, in the closed positions , the rams 127, 128, 129 advance radially into the main bore 124 to close and seal the main bore 124 (e.g., the rams 127) or the ring around the tubular chain 116 (e.g., rams 128, 129). Each of the battering groups 127, 128, 129 is driven and transited between the open and closed positions by a pair of servomotors 126. Specifically, each of the servomotors 126 hydraulically moves a piston inside a cylinder to move a driving rod coupled to one of the batchers 127, 128, 129.

Referring still to Figure 1, the LMRP 140 has a body 141 with an upper end 141a connected to the lower end of the coating pipe extension 115, a lower end 141b releasably secured to the upper end 123a with the connector 150 and a through hole 142 extending between the upper and lower ends 141a, b. The through bore 142 is aligned coaxially with the main bore 124 of the BOP 110, thereby allowing fluid communication between the through bore 142 and the main bore 124. The LMRP 140 also includes an annular burst preventer 142a comprising an annular elastomeric sealing element that is mechanically compressed radially inwardly to seal over a tubular extending through through hole 142 (eg, chain 116, casing line, drill pipe, ring perforation, etc.) or to seal the perforation 142. Therefore, the annular BOP 142a has the ability to seal a variety of pipe sizes and seal the perforation 142 when no tubular extends therethrough.

Referring now to Figures 1 and 2, in this embodiment, the upper end 141a of the LMRP 140 comprises a flexible liner pipe extension gasket 143 which allows the extension of the liner pipe 115 to be angularly biased relative to the BOP 120 and the LMRP 140 while the hydrocarbon liquids run from the well 101, the BOP 120 and the LMRP 140 to the extension of the casing 115. In this embodiment, the flexible joint 143 includes a cylindrical base 144 secured in the form rigid to a mating plug or mandrel 151 extending from the upper end of the LMRP 140 and an extension or lining pipe extension adapter 145 extending upwardly from the base 144. A liquid stream passage 146 that is extends through the base 144 and the adapter 145 defines the upper part of the through hole 142. A flexible element (not shown) disposed of The base 144 extends between the base 144 and the liner extension adapter 145 and is sealingly engaged with the base 144 and the liner pipe extension adapter 145. The flexible element allows the adapter Liner Pipe Extension 145 pivots and deflects angularly relative to the base 144, LMRP 140 and BOP 120. The distal base 144 of the upper end of the adapter 145 comprises an annular flange 145a for coupling the extension adapter of casing pipe 145 to an annular coupling flange 118 at the lower end of the extension of casing 115 or alternative devices. As best shown in Figure 3, the flange 145a includes a plurality of circumferentially spaced holes 147 that receive bolts to secure the flange 145a to an annular coupling flange 118 at the lower end of the coating pipe extension 115. In addition, the flange 145a includes a pair of circumferentially spaced guide holes 148, each guide hole 148 having a diameter greater than the diameter of the holes 147. In this embodiment, the flexible joint 143 also includes an intensification line of mud 149 having an inlet (not shown) in fluid communication with current passages 142, 146, an outlet 149b and a valve 149c configured to control the flow of liquids through line 149. Although it has been shown and disclosing that the LMRP 140 includes a particular flexible joint 143, in general, any flexible pipe extension pipe may be used adequate training in the LMRP 140.

As previously described, in this embodiment, the BOP 120 includes three battering groups (one set of cutting rams 127 and two groups of pipe rams 128, 129), although in other embodiments, the BOP (eg, the BOP) 120) may include a different number of battering rams (for example, four groups of battering rams), different types of battering rams (for example, two sets of battering rams and two groups of battering rams, one or more opposing blind battering groups), an annular BOP (eg, annular BOP 142a), or combinations thereof. It should be appreciated that the BOP 120 is an example only and that any submarine BOP preferably includes at least three groups of rams that include at least two groups of pipe rams and at least one group of blind rams. Similarly, while it is shown and described that the LMRP 140 includes an annular BOP 142a, in other embodiments, the LMRP (eg, the LMRP 140) may include a different number of annular BOPs (e.g., two BOP groups). annular), different types of battering rams (eg, battering rams), or combinations thereof.

Referring now to Figure 4, during a "kick" or inflow of liquid pressure from the formation in the well 101, one or more rams 127, 128, 129 of the BOP 120 and / or the annular BOP 142a of the LMRP 140 they are normally operated to seal well 101. In the event that well 101 is not sealed, this can potentially result in the discharge of such hydrocarbon liquids under the sea. In Figure 4, system 100 is shown after an underwater burst. In the burst situation example shown in Figure 4, the length of casing 115 has been cut and bent over the proximal flexible joint 143. As a result, the hydrocarbon liquids are running up into well 101 passing through. through the BOP 120 and the LMRP 140 and they discharge into the seawater surrounding them near the bottom of the sea 103 through the perforations and breaks in the extension of casing 115. The hydrocarbon liquids emitted form a submarine hydrocarbon plume 160 that extends towards the surface of the sea 102. The embodiments of containment caps and deployment methods described in more detail below are designed to contain and close well 101 and control the submarine emission of hydrocarbon liquids to reduce and / or eliminate underwater discharge of hydrocarbon liquids. .

Referring now to Figures 5 and 6, there is shown an embodiment of a containment stack or cap 200 for plugging the well 101 previously described (Figure 4) and containing the hydrocarbon liquids therein. In this embodiment, the containment cover 200 is modular, which means that the cover 200 comprises distinct and separate sections or assemblies that unfold under the sea independently and then couple together under the sea to form the cover 200. Specifically, the containment cap 200 comprises three assemblies: a first lower mount 210, a second upper mount 250 releasably coupled to the lower mount 210 with a wellhead type connection 150 and a death-countercurrent assembly 290 coupled in shape removable to the upper mount 250 with a well-hole type connection 150. As will be described in more detail below, the assemblies 210, 250 work together to contain and close well 101, while assembly 290 functions to supply death-weight liquids to well 101 and / or produce well 101 once it is contained and controlled.

In this embodiment, each of the assemblies 210, 250, 290 is sized and configured to be suitable for air cargo alone or in conjunction with another assembly 210, 250, 290. In other words, each of the assemblies 210, 250 , 290 has a weight and dimensions suitable for air transport. Conventional cargo aircraft such as the Antonov AN124 and Boeing 747 have a payload capacity of 120 tons (240 x 103 pounds) and load compartments sized to accommodate loads that have a maximum width of up to 6, 30 meters and a maximum height of up to 4.20 meters. In embodiments described herein, the lower assembly 210 has a weight of 70 tons (140 x 103 pounds), the upper assembly 250 has a weight of 40 tons (80 x 103 pounds) and the death-countercurrent assembly 290 has a weight of 7.5 tons (15 x 103 pounds). In addition, each of the assemblies 210, 250, 290 is dimensioned in such a way that it can be oriented to have a width of less than 6.30 meters and a height of less than 4.20 meters. For example, while the upper mount 250 may have a height greater than 4.20 meters, it is dimensioned such that it can be lowered and fit within the confines of the cargo compartment during boarding and then lift after transportation for deployment. Accordingly, any two of the three assemblies 210, 250, 290 can be transported together by air in a single cargo plane. The assembly 210, 250, 290 that is not transported with another assembly 210, 250, 290 can be transported in a separate cargo plane. As previously described, conventional closure piles are not dimensioned and configured to be transported by air because their weight exceeds the load capacity of conventional cargo aircraft and / or their dimensions can not be accommodated by the cargo compartments of the conventional cargo planes. Accordingly, the transport of such conventional closure piles must be carried out by land and / or by ship, which, depending on the relative locations of the maritime outbreak and the closure stack, may take time. For example, if there is an underwater explosion in the Gulf of Mexico, and the most appropriate closure pile to contain that outburst is located in the Middle East, it can take days or even weeks to transport the closure pile by land and sea to the maritime location in the Gulf of Mexico. However, the embodiments of containment caps described herein (eg, cap 200) are suitable for air cargo and therefore, can be transported around the globe in a matter of hours or a short number of days ( for example, from one to two days maximum). Accordingly, the embodiments described herein offer the potential to contain in a more efficient and timely manner an underwater explosion, reducing that the total volume of submarine hydrocarbon emissions.

Referring now to Figures 5-10, the lower mount 210 includes a frame 211 and a spool shaft or body 221 disposed within the frame 211. The frame 211 supports the spool body 221 and other components of the lower mount 210. In addition , the frame 211 protects the spool body 221 and other components of the lower mount 210 from impacts during transport and deployment.

The spool body 221 includes a first spool or piece of pipe reel 222 and a second reel or piece of pipe reel 230 attached and extending perpendicularly from the spool piece 222. The spool piece 222 has a central axis or longitudinal 223, a first upper end 222a, a second lower end 222b opposite the end 222a, a vertical through hole or perforation 224 extending axially between the ends 222a, b and a current perforation 225 extending perpendicularly from the bore 224. The upper end 222a of the first spool piece 222 defines the upper end of the spool body 221 and the lower end 222b of the first spool piece 222 defines the lower end of the spool body 221. The through bore 224 is disposed in the form coaxial inside the reel piece 222. In other words, drilling the through-hole 224 has a central axis that coincides with the axis 223. The through-hole 224 has a minimum inside diameter equal to or greater than the inside diameter of the well 101, the through hole 142 and the main hole 124 and can therefore be described that the through hole 224 has a "full bore diameter" and that it provides a "full drill access".

The upper end 222a of the spool piece 222 comprises an upward facing plug 150a and the lower end 222b comprises a downward facing pocket 150b. The plug 150a at the upper end 222a extends axially upwardly from the frame 211 and is configured to engage, engage and latch with the downwardly complementary complementary connector 150b on the upper assembly 250, thereby forming a hydraulically operated mechanical connection. , of the mouth type of the removable well 150 between the assemblies 210, 250. As will be described in more detail below, the receptacle 150b at the lower end 222 is configured to engage, engage and latch with a complementary upwardly facing plug 150a on a transition spool 330, BOP 120 or manhole 130 , thereby forming a hydraulically operated mechanical connection of the mouth of the releasable well 150 between the lower assembly 210 and the flexible joint adapter 145, the BOP 120 or the mouth of the well 130, respectively.

Referring still to Figures 6-10, the second spool piece 230 extends perpendicularly from the first spool piece 222 and has a central or longitudinal axis 231, a first radial inner end 230a (relative to axis 223) secured to the spool piece 222, a second radial outer end 230b (in relation to the axis 223) opposite the end 230a and the distal spool piece 222, and a horizontal current piercing or axially extending through hole 232 (in connection with shaft 231) between the ends 230a, b. The through hole 232 is coaxially disposed within the spool piece 230 and therefore, the through hole 232 has a central axis which coincides with the axis 231.

The through-hole 232 is coaxially aligned and contiguous with the horizontal bore 225. Therefore, the through bore232 is in fluid communication with the bore 225. Boards, the bores 225, 232 define a horizontal branch or path in the bore. reel body 221 extending perpendicularly from the main vertical bore 224. As best shown in Figure 10, the first reel piece 222 includes a valve 233 positioned along the bore 225 and the second spool piece 230 includes a valve 233 positioned along the through bore 232. The valves 233 control the flow of liquids through the bores 225, 232. That is, each of the valves 233 has an open position It allows the flow of liquids through it and a closed position that restricts the flow of liquids through it. The valves 233 are positioned in series along the perforations 225, 232. Accordingly, the flow of liquids through the perforations 225, 232 is restricted and / or prevented if one or both valves 233 are closed and the current of liquids through holes 225, 232 is allowed if both valves are open. In general, each of the valves 233 may comprise any type of valve suitable for anticipated liquid pressures and liquids in the bore 232 including, but not limited to, ball valves, gate valves and throttle valves. In addition, each of the valves 233 may be a manually operated, hydraulically actuated, mechanically driven or electrically operated valve. In this embodiment, each of the valves 233 is a hydraulically actuated gate valve valve for a differential pressure of 15k psi. Each of the valves 233 can be controlled and operated hydraulically under the sea with an ROV. Alternatively, each of the valves 233 can be controlled from the surface with hydraulic current lines or overhead wires extending from the surface engaging the valves 233 through a panel located on the lower mount 210.

The lower mount 210 also includes a throttle valve 234 positioned between a liquid conduit 235 and the spool piece 230. The liquid conduit 235 has a first end 235a coupled to the throttle valve 234, a second end 235b distal to the throttle valve 234 and a current bore 236 extending between the ends 235a, b. The ends 230b, 235a are coupled to the throttle valve 234 and the perforations 232, 236 are in fluid communication with the throttle valve 234. Therefore, the throttle valve 234 can comprise any throttle or throttle valve suitable for regulating the velocity of the liquid stream between the perforations 232, 236. In this embodiment, the throttle valve 234 is a Willis CC40 Control Choke with SLCA Hydraulic Stepped Actuation capability (non-functional) or mechanical stepped capability with a torsion available at Cameron International Corporation of Houston, Texas. The throttle valve 234 has a recoverable insert that can be removed and replaced under the sea.

The second end 235b of the liquid conduit 235 comprises an upward facing plug 239a configured to engage, engage and latch with a connector facing downstream of a current line to form a detachable current line connection therebetween. Therefore, with each of the 233 valves open, the liquid inside the through hole 224 is free to run through the perforations 225, 232, the throttle valve 234 and the bore 236 towards the plug 239a at the end 235b, where the liquid can be discharged into the surrounding sea or run inside another device connected to the 239a plug on end 235b. For example, as will be described in more detail below, when the lower assembly 210 is coupled to the well 101 and each of the valves 233 is open, the hydrocarbons discharged from the well 101 can run from the perforation 234 through the perforations 225. , the throttle valve 234 and the bore 236 towards the plug 239a at the end 235b, where the hydrocarbons can be discharged into the surrounding sea or produce another device connected to the plug 239a at the end 235b. Alternatively, with each of the valves 233 open, the liquid can be supplied and / or pumped from a device connected to the plug 239a through the bore 236, the throttle valve 234 and the bores 232, 225 towards the perforation 234. For example, as will be described in more detail below, when the lower assembly 210 is coupled to the well 101, chemical compounds or liquids of death weight can be supplied and / or pumped from a device connected to the plug 239a through the perforation 236, the throttle valve 234 and the perforations 232, 225 towards the hydrocarbons in the perforation 224.

As best shown in Figure 10, a first ring line 237 and a second ring line 238 provide access to the through hole 224 axially above and below the bore 225, respectively. Specifically, the first ring line 237 has a first radial inner end 237a in fluid communication with the through bore 224 and a second radial outer end 237b extending towards the outer surface of the spool piece 222 and the second ring line 238 has a first radial inner end 238a in fluid communication with the through bore 224 and a second radial outer end 238b extending towards the outer surface of the spool piece 222. The end 237a is positioned axially above the bore 225 and the end 238a is positioned axially below perforation 225. Ends 237b, 238b can be accessed by an ROV or other device as desired. In this embodiment, a valve 233 as previously described is positioned along each of the current lines 237, 238 between the ends 237a, b and 238a, b, respectively. Lines 237, 238 can be used to produce well 101 once it has been contained and controlled.

Referring still to Figure 10, in this embodiment, the bottom mount 210 also includes a chemical compound injection system 240 and a liquid sensor or monitoring system 226. For purposes of clarity, the injection system of Chemical compounds 240 and the liquid monitoring system 226 are not shown in Figures 6-9. The chemical compound injection system 240 includes a first stream line 241 for injecting chemical compounds into bore 232, a second stream line for injecting chemical compounds into bore 224 above bore 225 and a third stream line 243 for injecting chemical compounds into the perforation 224 above the second stream line 242. The upstream ends of the streamlines 241, 242, 243 converge on a common entry port of a double-door ROV servomechanism receptacle 248 Chemical compounds such as methanol and glycol can be supplied and / or pumped through the current lines 241, 242, 243 through the input receptacle 248.

Each of the flow lines 241, 242, 243 includes a main valve 245 for controlling the flow of the chemical compounds through the stream line 241, 242, 243. That is, each of the valves 245 has a position open that allows the flow of liquids through it and a closed position that restricts and / or prevents the flow of liquids through it. Accordingly, the flow of liquids through a specific current line 241, 242, 243 is restricted and / or prevented if its corresponding valve 245 is closed and the flow of liquids through a particular current line 241, 242, 243 is allowed if its corresponding valve 245 is open.

In general, each of the valves 245 can comprise any type of valve suitable for pressures of anticipated liquids and liquids of the streamlines 241, 242, 243 including, but not limited to, ball valves, gate valves and valves of butterfly. In addition, each of the valves 245 may be a manually operated, hydraulically actuated, mechanically operated or electrically operated valve. In this embodiment, each of the valves 245 is a hydraulically actuated gate valve operated for a differential pressure of 15k psi. Each of the valves 245 can be controlled and operated hydraulically under the sea with an ROV. Further, in this embodiment, the valve 245 on each of the current lines 242, 243 includes a check valve that allows the fluid communication of a path from the inlet receptacle 248 to the bore 224. The valve 245 on the Current line 241 does not include a check valve such that pressure testing and extraction of samples from bore 232 can be performed. Each of the current lines 242, 243 also includes a manometer 246 positioned between the valve 245 and its inlet receptacle 248. The meters 246 measure the liquid pressure within the current lines 242, 243. The secondary valves 247 are positioned along the current lines 242, 243 between the meters 246 and the receptacle. inlet 248 and an additional secondary valve 247 is positioned in the inlet receptacle 248. The valves Secondary 247 provide a secondary means for valves 245 to control the current lines through the current lines 241, 242, 243. In general, each of the valves 247 can comprise any type of valve suitable for liquid pressure. anticipated and the liquids of the current lines 241, 242, 243 which include, but are not limited to, ball valves, gate valves and butterfly valves. In addition, each of the valves 247 may be a manually operated, hydraulically actuated, mechanically operated or electrically operated valve. In this embodiment, each of the valves 247 is a manually operated needle valve qualified for a 15k psi differential pressure. Each of the valves 247 can be operated manually under the sea with an ROV. Alternatively, each of the valves 247 can be hydraulically controlled from the surface with hydraulic current lines or overhead wires extending from the surface and engaging the valves 247 through a panel located on the lower mount 210.

Referring still to Figure 10, the liquid monitoring system 226 includes an electronic pressure transducer 227 positioned along the through bore 224 and a temperature transducer 228 positioned along the through bore 224. The transducers 227 , 228 measure and monitor the pressure and temperature, respectively, of liquids within borehole 224. Each of the transducers 227, 228 are electronically coupled to an electrical coupling 229 configured to transmit the transduced temperature and pressure data, respectively, from the transducers 227, 228, to a submarine ROV or other device connected to the coupling 229.

Referring now to Figures 5, 6 and 11-14, the upper assembly 250 includes a frame 251 and a reel or pipe reel piece 260 disposed within the frame 251. The frame 251 holds the reel piece 260 as well as the reels. remaining components of upper mount 250. In addition, frame 251 protects spool piece 260 and the remaining components of upper mount 250 from impacts during transport and deployment. The upper part of the frame 251 comprises a planar buffer 252 to support the death-countercurrent assembly 290.

The spool piece 260 has a central or longitudinal axis 261, a first upper end 260a, a second lower end 260b and a through hole or perforation 262 extending axially between the ends 260a, b. The current perforation 262 is arranged coaxially within the spool piece 260. In other words, the current perforation 262 has a central axis which coincides with the axis 261. In this embodiment, the spool piece 260 is oriented in a manner such that the shaft 261 and the current perforation 262 extend vertically. In addition, in this embodiment, the drilling of stream 262 has a minimum inside diameter that is smaller than the minimum inside diameter of through hole 224 and well 101.

The upper end 260a of the spool piece 260 comprises an upward facing plug 150a and the lower end 260b comprises a downwardly facing receptacle 150b. The plug 150a at the upper end 260a extends axially upwardly from the buffer 252 and is configured to engage, engage and latch with a complementary downwardly facing connector 150b on the mount 290, thereby forming a hydraulically operated mechanical connection of type of the removable well mouth 150 between the assemblies 250, 290. Further, the receptacle 150b at the lower end 260b is configured to engage, engage and latch with a complementary upwardly facing plug 150a at the upper end 222a of the piece of reel 222, thereby forming a hydraulically actuated mechanical connection of the tear-mouth well type 150 between the assemblies 210, 250.

As best shown in Figures 12-14, the spool piece 260 also includes a first lower valve 263, a second upper valve 263 and a current piercing access member 265, each positioned along the bore stream 262 between the ends 260a, b. More specifically, the second valve 263 is axially spaced above the first valve 263 and access member 265 is positioned axially between valves 263. Valves 263 control the flow of liquids within bore 262. That is, each of valves 263 has an open position that allows the flow of liquids through it and a closed position that restricts and / or prevents the flow of liquids through it. The valves 263 are positioned in series along the current bore 262. Accordingly, the flow of liquids through the bore 262 is restricted and / or prevented if one or both of the valves 263 are closed and the flow of liquids a through perforation 262 is allowed if both valves 263 are open. In general, each of the valves 263 may comprise any type of valve suitable for anticipated liquid pressures and liquids within the bore 262 including, but not limited to, ball valves, gate valves and throttle valves. In addition, each of the valves 263 may be a manually operated, hydraulically actuated, mechanically operated or electrically operated valve. In this embodiment, each of the valves 263 is a hydraulically operated gate valve qualified for a 15k differential pressure. psi. Each of the valves 263 can be controlled and operated hydraulically under the sea with an ROV. As will be described in more detail below, the current piercing access member 265 allows access to the current piercing 262.

Referring now to Figure 14, in this embodiment, the top assembly 250 also includes a chemical compound injection system 270 and a liquid sensor or monitoring system 280. For clarity purposes, the system for injecting chemical compounds 270 and the liquid monitoring system 280 are not shown in Figures 5, 6 and 11-13. The chemical compound injection system 270 includes a provision line 271 that can be used to inject chemical compounds into the bore 262 and a return line 272 to receive liquids from the bore 262. The provision line 271 has an inlet end 271a and a second outlet end 271b in fluid communication with the bore 262 through the access member 265. The return line 272 has a first inlet end 272a in fluid communication with the bore 262 through the access member 265 and a second output end 272b. The inlet end 271a and the outlet end 271b are connected to separate doors on a double door ROV servomechanism receptacle 248. Chemical compounds such as methanol and glycol can be supplied and / or pumped through the supply line 271 perforation 262 can be acquired and drilling liquids 262 can be acquired through the return line 272. As will be described in more detail below, the supply and return lines 271, 272 can also be used to acquire samples of well liquids for the measurement and monitoring of pressure and / or temperature.

Each of the current lines 271, 272 includes a pair of valves 273, arranged in series, to control the flow of chemical compounds through that particular current line 271, 272. That is, each of the valves 273 has an open position that allows the flow of liquids through it and a closed position that restricts and / or prevents the flow of liquids through it. Accordingly, the flow of liquids through a particular stream line 271, 272 is restricted and / or prevented if one or both of its valves 273 is closed and the fluid stream through a particular stream line 271, 272 it is allowed if both of its corresponding valves 273 is open. In general, each of the valves 273 may comprise any type of valve suitable for liquid and liquid pressures within the streamlines 271, 272, including, but not limited to, ball valves, gate valves and valves of butterfly. In addition, each of the valves 273 may be a manually operated, hydraulically operated, mechanically operated or electrically operated valve. In this embodiment, each of the valves 273 is a manually operated needle valve qualified for a 15k psi differential pressure. Each of the valves 273 can be operated manually under the sea with an ROV. In this embodiment, the return line 272 includes a manometer 246 positioned between the valves 273 and the access member 265. The meter 246 measures the pressure of the liquid within the return line 272.

With reference still to Figure 14, the liquid monitoring system 280 includes a drilling liquid supply line 281, a drilling fluid return line 282 and a 285 sensor package or assembly. The current line 281 has an inlet end 281a in fluid communication with the current bore 262 through the access member 265 and an outlet end 281b comprising a coupling 283. The stream line 282 has an inlet end 282a comprising a coupling 283 and an outlet end 282b in fluid communication with the current perforation 262 through the access member 265. Each of the stream lines 281, 282 includes a valve 247 that was previously described to control the flow of liquids to through that particular current line 281, 282. The sensor package 285 includes a liquid stream line 286, a pressure sensor 287 disposed along line 286, a temperature sensor 288 disposed along line 286 and a data transmitter 289. coupled to the sensors 287, 288. The stream line 286 has an inlet end 286a comprising a coupling 284 detachably coupled to the coupling 287 of the line 281 and an outlet end 286b comprising a coupling 284 coupled in removable form to the coupling 283 of the line 282. Therefore, the current lines 281, 282, 286 create a loop of liquid stream of the perforation, the liquids of the perforation of current flow through the line 281, 286 and 282 back to the current drilling 262. The sensors 287, 288 measure the pressure and temperature, respectively, of the drilling liquids running through line 286. The measured pressure and temperature data are communicated to the transmitter 288, which then wirelessly retransmits the measured pressure and temperature data to the surface. The transmitter 289 can communicate pressure and temperature data periodically or in real time. In general, the transmitter 289 can be any suitable device for transmitting data from an underwater location to the surface. In this embodiment, the transmitter 289 is an acoustic data logger. As described above, sensor pack 285 is detachably coupled to lines 281, 282 through couplings 283, 284. Thus, sensor pack 285 can be removed or coupled to access member 265 as appropriate. want. One or more ROVs can be used to connect sensor pack 285 to lines 281, 282 and to disconnect sensor pack 285 from lines 281, 282.

In this embodiment, systems 270, 280 use separate supply and return lines. That is, the system 270 includes the provision line 271 and the return line 272 and the system 280 includes the provision line 281 and the return line 282. However, in other embodiments, the liquid monitoring system (for example, example, system 280) can use the same supply and return lines as the system of injection of chemical compounds (for example, system 270). For example, the sensor pack 285 may be configured to be plugged into the servo receptacle 248, to receive liquids from the well through the supply line 271 and to return liquids from the well through the return line 272. In other words , the ends 286a, b of the current line 286 may be configured as doors in a servomechanism connector that is coupled to the receptacle 248 with the inlet end 286a in fluid communication with the supply line 271 and the outlet end 286b in fluid communication with the return line 272.

Referring now to Figures 5, 6, 15 and 16, the counter-current assembly 290 includes a frame 291 and a reel or piece of pipe reel 292 extending through the frame 291. The frame 291 holds the piece. of spool 292 as well as the remaining components of assembly 290. In addition, frame 291 protects spool piece 292 and the remaining components of assembly 290 from impacts. The lower end of the frame 291 comprises an annular funnel or guide 293 to facilitate mounting the support 290 on the upper assembly 250.

The spool piece 292 has a central or longitudinal axis 294, a first upper end 292a, a second lower end 292b opposite the end 292a, and a through hole or perforation 295 extending axially between the two ends. ends 292a, b. The current perforation 295 is arranged coaxially within the spool piece 292. In other words, the current perforation 295 has a central axis which coincides with the axis 294. In this embodiment, the spool piece 292 is oriented in a manner such that the shaft 294 and the current perforation 295 extend vertically. In this embodiment, the current perforation 295 has an inner diameter that is the same as the internal diameter of the current perforation 262.

The upper end 292a of the reel piece 292 extends axially upwardly from the frame 291 and comprises an upwardly facing flange 296 and the lower end 292b comprises a downwardly facing receptacle 150b. The flange 296 is configured to engage, engage and connect with a downwardly facing flange on a current conduit that provides death-weight liquids to the cap 200 and / or produces hydrocarbons from the well 101. In this embodiment, two examples of conduits 298, 299 in Figures 15 and 16. The receptacle 150b at the lower end 292 is configured to engage, engage and latch with the upwardly facing plug 150a at the upper end 260a of the spool piece 260, forming thereby a hydraulically operated mechanical connection, of the type of the removable well mouth 150 between the assemblies 250, 290.

Referring again to Figure 6, the upper mount 250 is removably coupled to the lower mount 210 with a wellhead type connection 150 and the death-countercurrent assembly 290 is removably coupled to the upper mount with a type connection of the wellhead 150. When the cover 200 is assembled as shown in Figure 6, the current perforations 224, 262, 295 are aligned coaxially, the current perforation 224 is in fluid communication with the current perforation 262 and the current perforation. 295 is in fluid communication with the current perforations 224, 262 provided that the valves 263 of the current perforation 262 are open. Therefore, with the valves 262 open, the liquids are free to run through the perforations 224, 262, 295 between the ends 222b, 292a. Therefore, when the cover 200 is coupled to the mouth of the underwater well 130, the BOP 120 or the LMRP 140, valves 263 are open and full access hole 224 is in fluid communication with well 101, deadweight liquids can be pumped into well 101 through line 298 or 299 during the death operations, or alternatively, hydrocarbons that run from well 101 can be produced through conduit 298 or 299.

In this embodiment, the containment cap 200 is designed to be deployed under the sea and supported on the flexible joint of the coating pipe extension 143 of the LMRP 140, on the mandrel 151 of the LMRP 140, on the BOP 120 or on the mouth of the well 130, depending on which of them is the most suitable support location. For example, in Figure 20L, the lid 200 is shown installed on the subsea BOP 120 previously described; in Figure 21, the lid 200 is shown installed above the mouth of the underwater well 130 previously described; and in Figure 30P, the lid 200 is shown installed on the flexible joint 143 of the LMRP 140 previously described. Regardless of the support / installation site, in this embodiment, the modular cover 200 previously described is installed in stages: first the bottom mount 210 is deployed under the sea and installed on the selected support site (eg, the LMRP 140, the mandrel 151, the flexible joint 143, the mouth of the well 130, the BOP 120), then the upper assembly 250 is deployed under the sea and is installed on the lower mount 210 and then the death-countercurrent assembly 290 is It deploys under the sea and is installed on top mount 250.

Referring briefly to Figures 17 and 18, in this embodiment, the lower mount 210 is lowered and handled under the sea with an operating tool 215 releasably coupled to the plug 150a at the upper end 222a of the spool piece 222. As best shown in Figure 18, the operating tool 215 has a first upper end 215a and a second lower end 215b opposite the end 215a. The lower end 215b comprises a receptacle downwardly facing 15b which engages removably to the plug 150a at the upper end 222a. The upper end 215a of the operating tool 215 can be removably coupled to a first adapter 216 that allows the deployment of the lower assembly 210 with a pipeline or drill string, or to a second adapter 217 that allows deployment of the assembly lower 210 on the cable. Therefore, the operating tool 215 can be deployed under the sea from a surface vessel with a pipe string using the first adapter 216 and the operating tool 215, or with a cable using the second adapter 217 and the tool operation 215. As shown in Figure 19, the upper assembly 250 is lowered and manipulated under the sea with the cable coupled to the frame 251 with a plurality of cable lines 253 disposed around the buffer 252. The death-countercurrent assembly 290 is lowered and handled under the sea with the cable in the same manner as the upper assembly 250. In other embodiments, the upper assembly 250 and / or the death-countercurrent assembly 290 can be lowered through a drill pipe. , pipe chain, flexible pipe, or coiled tubing.

Referring now to Figures 20A-20L, it is shown that the containment cover is deployed and installed under the sea on the BOP 120 to close and / or produce the well 101. More specifically, in Figures 20A-20D, it is shown that he lower mount 210 is lowered under the sea and coupled to the BOP 120; in Figures 20E-20F, it is shown that the upper mount 250 is lowered under the sea and coupled to the lower mount 210; and in Figures 20I-20L, it is shown that the death-countercurrent assembly 290 is being lowered under the sea and engaging the upper mount 250.

For the deployment and underwater installation of the containment cover 200, one or more vehicles operated by remote control (ROV) are preferably used to help position the assemblies 210, 250, 290, monitor the assemblies 210, 250, 290 and the BOP 120 and assemblies 210, 250, 290 (for example, actuate valves 233, 263, operate the systems for injection of chemical compounds, etc.). In this embodiment, three ROV 170 are used to position mounts 210, 250, 290, monitor mounts 210, 250, 290 and BOP 120 and operate mounts 210, 250, 290. Each of the ROV 170 includes an arm 171 having a hook 172, an underwater camera 173 for observing underwater operations (e.g., the relative positions of the assemblies 210, 250, 290, the BOP 120, the boom 160, the positions and movement of the arms 170 and the hooks 172, etc.) and a cable 174. The transmission of video and / or image from the cameras 173 is communicated to the surface or to another remote location through the cable 174 for live or periodic observation. The arms 171 and the hooks 172 are controlled through commands sent from the surface or from another location remote to ROV 170 through cable 174.

Before connecting the cover 200 to the BOP 120, the LMRP 140 is removed from the BOP 120 by decoupling the connection 150 between the BOP 120 and the LMRP 140 and then lifting the LMRP 140 from the BOP 120 with a cable, a chain of pipes, one or more ROV 170, or combinations of them. In addition, all tubulars or debris extending from the upper end 123a of the BOP 120 are cut substantially flush with the upper end 123a with one or more ROV 170.

Referring first to Figure 20A, in this embodiment, it is shown that the lower mount 210 is being controllably lowered under the sea with a pipe string 180 secured to the upper end of the adapter 216 and extending to a vessel Of surface. A suitable rig or gold rig mounted to the surface vessel is preferably used to hold and lower the assembly 210 on the chain 180. While the chain 180 is employed to deploy the bottom assembly 210 in this embodiment, in other embodiments, the Lower mount 210 can be deployed under the sea on a cable. Using the chain 180, the lower mount 210 is lowered under the sea under its own weight from a location generally above and laterally offset from the well 191 and the BOP 120. More specifically, during deployment, the lower mount 210 is preferably maintained out of the boom 160 of the hydrocarbon liquids emitted from the well 101. The descent of the lower mount 210 under the sea to the boom 160 can trigger the undesirable formation of hydrates within the lower mount 210, particularly at elevations substantially above the bottom from the sea 102 where the temperature of the hydrocarbons of boom 160 is relatively low.

Turning now to Figure 20B, the lower mount 210 is lowered laterally deviated from the BOP 120 and out of the boom 160 until the lower end 222b is slightly above the BOP 120. When the assembly 120 descends and approaches the BOP 120, ROV 170 monitors the position of assembly 210 in relation to BOP 120. Then, as shown in Figure 20C, the assembly 210 moves laterally to the position immediately above and substantially coaxially aligned with the BOP 120. One or more ROV 170 can use its hooks 172 and the frame 211 to guide and manipulate the position of the assembly 210 in relation to the BOP 120. Due to its own weight, the assembly 210 is substantially vertical, while the BOP 120 may be oriented at a slight angle relative to the vertical line. Therefore, it should also be understood that the perfect coaxial alignment of the BOP 120 and assembly 210 may be difficult. However, the coupling profiles of the plug 150a at the upper end 123a of the BOP 120 and the receptacle 150b at the lower end 222b of assembly 210 facilitate coaxial alignment and coupling of the assembly 210 and the BOP 120 when the assembly 210 is lowered from a position immediately above the BOP 120, even though the assembly 210 is at first slightly misaligned with the BOP 120.

Turning now to Figure 20D, with the receptacle 150b at the lower end 222b of the assembly 210 positioned immediately above and substantially aligned coaxially with the plug 150a at the upper end 123a of the BOP 120, the chain 180 lowers the assembly 210 axially downward. Due to the weight of the assembly 210, the compressive loads between the assembly 210 and the BOP 120 push the male plug 150a at the upper end 123a into the female receptacle 150b at the lower end 222b. Once the plug 150a is sufficiently supported in the receptacle 150b to form the mouth connection of the well 150, the connection 150 is hydraulically actuated to securely connect the assembly 210 to the BOP 120 as shown in Figure 20D .

When the assembly 210 is positioned immediately above the BOP 120, the hydrocarbons emitted from the BOP 120 are free to run unrestrictedly through the perforation 224. Furthermore, before moving the assembly 210 laterally on the BOP 120, the valves 233 in lines 237, 238 are closed and valves 233 in bores 225, 2232 are opened to allow hydrocarbon liquids emitted by the BOP 120 run through the bore 232, the choke 234 and the bore 236. The valves 233 of the bores 225, 232 can transit to the open position and the valves 233 of the lines 237, 238 can transit to the closed position in the surface 102 before deployment, or under the sea through one or more ROV 170. Therefore, when an assembly 210 moves laterally over the BOP 120 and is lowered to engage it with the BOP 120, the hydrocarbon liquids emitted run As a result, the open valves 233 offer the potential to reduce the resistance to axial insertion of the plug 150a into the receptacle 150b and the coupling of the lower mount 210 to the BOP 120. In other words, the open valves 233 in the perforations 225, 232 allow the relief of the pressure of the well during the installation of the lower assembly 210. With a secure, sealed connection between the lower mount 210 and the BOP 120, the ROV 170 disconnect the operating tool 215 from the lower mount 210. The operating tool 215 and the adapter 216 can then be removed to the surface with the pipe chain 180.

Referring now to Figure 20E, with the bottom mount 210 securely attached to the BOP 120, the top mount 250 unfolds and engages the bottom mount 210. In this embodiment, it is shown that the top mount 250 is being lowered in controllable shape with the cable 181 extending from a surface vessel and having a lower end secured to the cables 253. Due to the weight of the assembly 250, the cable 181 and the cables 253 are preferably relatively strong cables (e.g., steel cables) capable of supporting the loads of traction anticipated. Preferably a winch or a crane mounted to a surface vessel is used to hold and lower the assembly 250 on the cable 181. While the cable 181 and the cables 253 are used to lower the assembly 250 in this embodiment, in other embodiments, assembly 250 can be deployed under the sea on a pipeline chain. Using the cable 181, the assembly 250 is lowered under the sea under its own weight from a location generally above and laterally offset from the well 101, the BOP 120, the lower mount 210 and out of the boom 160 to reduce the potential of the formation of hydrates within assembly 250.

Turning now to Figure 20F, the upper assembly 250 is lowered sideways from the lower assembly 210 and out of the boom 160 until the lower end 260b is slightly above the lower assembly 210. When the upper assembly 250 descends and approaches the assembly lower 210, the ROVs 170 monitor the position of the upper assembly 250 relative to the lower assembly 210. Then, as shown in Figure 20G, the assembly 250 moves laterally to the position immediately above and substantially aligned coaxially with the lower assembly 210. One or more ROV 170 can use its hooks 172 and the frame 251 for guiding and manipulating the position of the upper mount 250 relative to the lower mount 210. Due to its own weight, the mount 250 is substantially vertical, while the lower mount 210 can be oriented at a slight angle relative to the vertical line if the BOP 120 was slightly angled. Therefore, it should be understood that the perfect coaxial alignment of the assemblies 210, 250 can be difficult. However, the coupling profiles of the plug 150a at the upper end 222a of the spool piece 222 and the receptacle 150b at the lower end 260b of the mount 250 facilitate the coaxial alignment and coupling of the assemblies 210, 250 when the top assembly 250 is lowered from a position immediately above the lower assembly 210, even though the upper assembly 250 is at first slightly misaligned with the lower assembly 210.

Turning now to Figure 20H, with the receptacle 150b at the lower end 260b positioned immediately above and substantially aligned coaxially with the plug 150a at the upper end 222a, the cable 181 lowers the assembly 250 axially downward. Due to the weight of the assembly 250, the compressive loads between the upper assembly 250 and the lower assembly 210 push the male plug 150a at the upper end 222a into the female receptacle 150b at the lower end 260b. Once the plug 150a is sufficiently supported in the receptacle 150b to form the mouth type connection from well 150, connection 150 is hydraulically actuated to securely connect upper assembly 250 to lower assembly 210 as shown in Figure 20H. With a secure connection, sealed between the bottom mount 210 and the top mount 250, the ROV 170 uncouples the wires 253 from the bottom mount 210. The wires 253 can then be removed to the surface with the wire 181.

Before moving the upper assembly 250 laterally above the lower mount 210 and the BOP 120, the valves 263 transit to the open position which also allows the BOP 120 to eject the hydrocarbon liquids and the lower mount 210 to run through the perforation 262. Valves 263 can transit to the open position at the position on the surface 102 before deployment, or under the sea through one or more ROV 170. Therefore, when the upper assembly 250 moves laterally on the lower assembly 210 and lowered to mesh with lower mount 210, the hydrocarbon liquids emitted run freely through bore 262. Accordingly, open valves 263 offer the potential to reduce the resistance to axial insertion of plug 150a into the receptacle 150b and the coupling of the assembly 250 to the lower assembly 210. In other words, the open valves 263 allow the relief of the pressure d the well during the installation of the upper assembly 250. It should also be noted that the aligned perforations 225, 262 allow the re-entry of the BOP 120 and the well 101.

Referring now to Figure 201, with the upper mount 250 firmly attached to the lower mount 210, the dead-back assembly 290 is deployed and engages the upper mount 250. The mount 290 is deployed substantially in the same manner as the assembly upper 250. Specifically, in this embodiment, it is shown that the death-countercurrent assembly 290 is being controllably lowered under the sea with the cable 181 extending from a surface vessel and having a lower end coupled to the frame 291 with a plurality of cables 253. Due to the weight of the assembly 250, the cable 181 and the cables 253 are preferably relatively strong (e.g., steel cables) capable of withstanding the anticipated tensile loads. Preferably a winch or a crane mounted to a surface vessel is used to hold and lower the assembly 290 on the cable 181. While the cable 181 and the cables 253 are used to lower the assembly 290 in this embodiment, in other embodiments, the assembly 290 can be deployed under the sea on a chain of pipes. Using the cable 181, the assembly 290 is lowered under the sea under its own weight from a generally upward and laterally offset location of the well 101, the BOP 120, the lower mount 210, the top assembly 250 and out of the boom 160 to reduce the potential of hydrate formation within assembly 290.

Turning now to Figure 20J, assembly 290 is lowered laterally deviated from top assembly 250 and out of boom 160 and lower end 292b is slightly above top assembly 250. When assembly 290 descends and approaches top assembly 250, the ROV 170 monitors the position of the assembly 290 in relation to the top assembly 250. Then, as shown in Figure 20K, the assembly 290 moves laterally to the position immediately above and substantially aligned coaxially with the top assembly 250. One or more ROV 170 may use its hooks 172 and frame 290 to guide and manipulate the position of assembly 290 relative to top assembly 250. Due to its own weight, assembly 290 is substantially vertical, while upper assembly 250 may be oriented at a slight angle in relation to the vertical line if the BOP 120 was slightly angled. Therefore, it should be understood that the perfect coaxial alignment of the assemblies 250, 290 can be difficult. However, the coupling profiles of the plug 150a at the upper end 260a of the spool piece 260 and the receptacle 150b at the lower end 292b of the spool piece 292 facilitate the coaxial alignment and coupling of the assemblies 250, 290 since the assembly 290 is lowered from a position immediately above top assembly 250, even though assembly 290 is at first slightly misaligned with top assembly 250.

Turning now to Figure 20L, with the receptacle 150b at the lower end 292b positioned immediately above and substantially aligned coaxially with the plug 150a at the upper end 260a, the cable 181 lowers the assembly 290 axially downward. Due to the weight of the assembly 290, the compressive loads between the assembly 290 and the upper assembly 250 push the male plug 150a at the upper end 260a into the female receptacle 150b at the lower end 292b. Once the plug 150a is sufficiently supported in the receptacle 150b to form the mouth-type connection of the well 150, the connection 150 is hydraulically actuated to securely connect the kill-countercurrent assembly 290 to the top assembly 250 as shown in FIG. shown in Figure 20L. With a secure connection, sealed between the upper assembly 250 and the death-countercurrent assembly 290, the ROV 170 uncouples the cables 253 from the assembly 290. The cables 253 can then be removed to the surface with the cable 181.

Before moving the assembly 290 laterally on the upper assembly 250 and the BOP 120, the current perforation 295 is kept open to allow the BOP 120 to emit the hydrocarbon liquids and the assemblies 210, 250 to run through the perforation 295 Therefore, when the death-countercurrent assembly 290 moves laterally on the upper assembly 250 and is lowered to mesh with the upper assembly 250, the hydrocarbon liquids emitted run freely at through perforation 295, thereby offering the potential to reduce the resistance to axial insertion of the plug 150a into the receptacle 150b and the coupling of the mount 290 to the top mount 250. In other words, the perforation of current 295 allows the relief of the pressure of the well during the installation of the death-countercurrent assembly 290. A conduit 298, 299 may be coupled to the upper end 292a of the spool piece 292 (to provide liquids of death weight or to produce the well 101) once the assembly 290 is firmly connected to the upper assembly 250.

In the manner described, the cover 200 is deployed and installed on the BOP 120. However, as best shown in Figure 21, the cover 200 can also be installed directly above the well bore 130. The mounts 210, 25 , 290 deploy below the sea and connect together in the exact same manner as previously described except that the lower mount 210 is firmly connected to the well mouth 130. Specifically, the downward facing receptacle 150b at the lower end 222b engages the upwardly facing receptacle 150a of the mouth of the well 130, thereby forming the connection 150 center the lower assembly 210 and the mouth of the well 130. Before connecting the lower mount 210 to the wellhead 130, the LMRP 140 and the BOP 120 are removed from the wellbore 130 by decoupling the connection 150 between the BOP 120 and the LMRP 140, lifting the LMRP 140 from the BOP 140 and then uncoupling the connection 150 between the BOP 120 and the mouth of the well 130 and lifting BOP 120 from the well bore 130. In addition, all tubulars or debris extending from the well bore 130 are cut substantially flush with the upper end of the wellbore plug 150a with one or more ROV 170.

Referring now to Figures 6 and 20L, after installation of the containment cap 200, the hydrocarbons are free to run through the cap 200. To contain and close the well 101, the valves 253 in the perforations 225, 232 and valves 263 in bore 262 are manipulated with submarine ROVs 170. If death liquids are used to assist in closing well 101, the counter-current assembly 290 is preferably installed prior to initiating closure procedures (ie said, in such a way that death weight liquids can be provided to the lid 200 and the well 101 through the conduit 298). However, if death liquids are not used to assist closure in well 101, closure procedures may be initiated prior to the installation of the counter-current assembly 290.

To close the well 101, both valves 233 in the stream lines 237, 238 are closed and both valves 233 in the perforations 225, 232 are kept open while the top valve 263 is kept closed. When the upper valve 263 transits to the closed position, the pressure of the well liquids within the lower assembly 210 is monitored with the pressure transducer 227. and the pressure of the well liquids within the upper assembly 250 is monitored with the pressure sensor 287. As long as the pressure of the formation liquids within the assemblies 210, 250 is within limits acceptable, the upper valve 263 continues to close until it is fully closed. Once the upper valve 263 closes, the lower valve 263 can also be completely closed to provide redundancy. With both valves 263 closed, the liquid stream through the bore 262 is restricted and / or prevented, however, since the valves 233 in the bores 225, 232 open, the liquids of the formation are free to run through the perforations 224, 225, 232, 236 and the throttle valve 234. Then, the valve 233 in the bore 232 transits to the closed position. When that valve 233 transits to the closed position, the pressure of the well liquids within the lower assembly 210 is monitored with the pressure transducer 227. As long as the pressure of the formation liquids within the assembly 210 is within acceptable limits , the valve 233 in bore 232 continues to close until it is completely closed. Once valve 233 in bore 232 is closed, valve 233 in bore 225 can also be completely closed to provide redundancy. With each of the valves 233, 263 closed, the well 101 is contained and closed. It should be appreciated that the inclusion of the throttle valve 234 and the staged closure of the well 101 through of the consecutive closure of the valves 233, 263 allows a "soft" closure, thereby offering the potential to reduce the possibility of an abrupt pressure buildup, which can damage the underwater components (for example, the BOP 120, assembly 210, assembly 250, assembly 290) and drift into another underwater burst.

Once well 101 closes and is generally under control, and that the infrastructure needed to produce well 101 is in place (for example, hydrocarbon storage vessels, liners, collectors, current lines, etc. are installed), well 101 can be produced through death-countercurrent assembly 290 and / or conduit 235. For example, depending on the particular circumstances, well 101 can be produced through assembly countercurrent 290 with valves 233 closed and valves 263 open, produce through conduit 235 with valves 233 open and valves 263 closed, or produce through assembly 290 as well as conduit 235 with all valves 233, 263 open As previously described, the lower assembly 210 includes the chemical compound injection system 240, and the upper assembly 250 includes a chemical compound injection system 270. The injection systems 240, 270 can be used before, during or after close well 101, to inject chemical compounds in the perforations 224, 262, respectively and the well 101. For example, chemical compounds such as glycol and / or methanol can be injected to reduce the hydrate formations within the assemblies 210, 250 that could otherwise hamper or prevent the ability to install the assemblies 210, 250. As another example, chemical dispersants can be injected into the hydrocarbons that run through the assemblies 210, 250 after installation to mitigate the volume of oil and volatile organic compounds generated in the surface of the sea.

The containment cap 200 previously described can also be installed on the mandrel 151 or the flexible joint 143 of the LMRP 140. The installation of the cover 200 on the flexible joint 143 of the LMRP 140 will now be described. As shown in Figures 1 and 2, the coating pipe extension adapter 145 is coupled to the flexible joint 143, the upper end of the coating pipe extension adapter 145 comprises the flange 145a for coupling the adapter 145 to the coupling flange 118 on the bottom end of the liner extension 115. However, in the embodiment shown, the lower end 222b of the reel piece 222 (Figure 8) comprises the receptacle 150b for connection to a compntary mating socket 150a to form a connection of the mouth of the well 150. Therefore, the receptacle 150b is not configured or designed to attach it and engage it to tab 145a. therefore, with reference now to Figure 22, in this embodiment, a transitional adapter or spool 330 is used to couple the lower mounting 210 of the cover 200 to the adapter of the coating pipe extension 145.

Referring now to Figure 22, in this embodiment, the transition spool 330 has a central or longitudinal axis 335, a first upper end 330a, a second lower end 330b opposite the end 330a, and a current perforation 331 extending axially between the ends 330a, b. the upper end 330a comprises an upwardly facing plug 150a configured to removably engage the compntary receptacle 150b, at the lower end 222b of the containment cap 200 to form a mouth-type type connection 150, the lower end 330b comprises a male shoe 340 configured to be inserted coaxially into the liner pipe extension adapter 145 after removal of the liner pipe extension 115 from the flexible joint 143. An annular flange 334 is axially disposed between the ends 330a by, is dimensioned and configured to engage and mesh with the flange 145a of the flexible joint 145. The flange 334 includes a plurality of the circumferentially spaced holes 334a. The bolts 334b are pre-arranged in the holes 334a and an elastic annular band 336 is disposed around the upper ends of the holes 334b. The band 336 pushes the upper ends of the bolts 334b radially inward relative to their lower ends and holes 334a, biasing and angling the bolts 334b relative to the bolts 334a (ie, the bolts 334b are not aligned coaxially with the bolts 334a). the holes 334a). In this way, the band 336 maintains the position of the bolts 334b which extend into the holes 334a during the deployment of the transition spool 330, thereby reducing the possibility of one or more bolts 334b disengaging from their corresponding holes. 334a and fall to the bottom of the sea 103 during the deployment and installation of the containment cover 200.

Referring still to Figure 22, a pair of circumferentially spaced apart alignment guides or pins 338 extend axially downwardly from flange 334. Dowels 338 are dimensioned and positioned to coaxially and rotationally align flange 334 of the transitional spool 330 in relation to the flange 145a of the flexible joint 143 so that the holes 334a are aligned coaxially with the corresponding holes in the flange 145a. The transition spool 330 also includes a plug 337 that extends axially through the flange 334. The cap 337 is positioned and oriented for axial insertion into the outlet 149b of the mud intensification line 149 in the flange 145a when the tabs 145a, 334 are coupled together. The plug 337 it functions to close and seal the outlet 149b, thereby preventing the spillage of hydrocarbon liquids therethrough in the event that the sludge intensification valve 149c fails or has spills otherwise. In this embodiment, the cap 337 is pre-installed on the transition spool 330 prior to deployment such that it meshes with the coupling outlet 149b when the flanges 145a, 334 are in contact. Alternatively, the plug 337 can be installed by an ROV 170 after the flanges 145a, 334 are secured together. The plug 337 can be fitted with an adapter for coupling a supply line of chemical compounds to the plug 337 to inject a chemical compound at the outlet 149b in the event that it is necessary to flood hydrates from the outlet 149b.

The male shoe 340 is a tubular that extends axially downwardly from the flange 334. In this embodiment, the shoe 340 also includes a plurality of elongated, circumferentially spaced through grooves 343 extending radially from the outer cylindrical surface of the shoe. 340 to the perforation 331. In the embodiment, the slots 343 are oriented parallel to the shaft 335. In other embodiments, the slots of the shoe (eg, the slots 343 in the shoe 340) can be omitted. Further, while this embodiment of the transition spool 330 includes the shoe 340, in other embodiments, the shoe (eg, the shoe 340) is removed completely. In such embodiments, a plurality of guide pins (e.g., guide pins 338) facilitate alignment and engagement of the transition spool (e.g., spool 320) and flexible joint (e.g., flexible joint 143). ).

As will be described in more detail below, during the installation of the transition spool 330 on the flexible joint 143, the shoe 340 is aligned coaxially with the seal 143 and is axially advanced in the joint 143 and the flanges 145a, 334 are axially supported. During the insertion of the shoe 340 into the flexible joint 143, the through slots 343 provide a current path for the hydrocarbon liquids discharged from the well 101 through the BOP 120 and the LMRP 140, thereby offering the potential to relieve the pressure of the well during the installation.

To facilitate the alignment and insertion of the shoe 340 into the flexible joint 143, the lower end 330b is angled and tapering in the side view (i.e., when viewed perpendicular to the axis 335). Specifically, the lower end 330b is oriented at an angle β in relation to the axis 335. The angle β is preferably between 30 ° and 60 °. In this embodiment, the angle ß is 45 °. The tapered lower end 330b also facilitates axial advancement of the shoe 340 into another component (eg, flexible joint 143) that is bent or placed at an angle in relation to the vertical line and / or containing pipes or tubulars arranged in it. For example, the shoe 340 can be inserted into another component and advance axially in a slow manner. When the shoe 340 comes forward, the tapered end 330b slidably engages the component, thereby guiding the shoe 340 in the component. In addition, the tapered end 330b slidably engages and guides the tubulars within the component in the bore 331. In other words, the tapered end 330b allows the shoe 340 to radially wedge itself between the component and the tubulars disposed in he. This can be particularly advantageous in cases where the shoe 340 engages a component containing tubulars or damaged pipes that can not be removed.

To prepare the flange 145a to seal the gear with the flange 334, the coating pipe extension 115 is removed from the flexible joint 143 and all tubular or debris extending upwardly from the flange 145a is preferably cut substantially flush with the flange. tab 145a. Further, the liner extension adapter 145 is preferably vertically oriented and locked in the vertical position before coupling the transition spool 330, the lower mounting 210, the upper assembly 250, the death-countercurrent assembly 290, or combinations of them to the pipeline extension adapter 145. This offers the potential to simplify the installation of these components as well as reduce the moments experienced by the adapter 145 after the installation of these components. More specifically, since the lining pipe extension adapter 145 is designed to deflect at an angle and pivot relative to the base 144, the moments exerted on the lining pipe extension adapter 145 after assembly of such components it can cause the liner extension adapter 145 to pivot and / or break undesirably. However, by straightening the flexible joint 143 (i.e., orienting the adapter of the casing extension 145 vertically) and locking the adapter of the casing extension 145 in place, such moments can be reduced and resisted without Adapter 145 pivots or breaks. In general, the pipeline extension adapter 145 can be oriented vertically and locked in the vertical orientation by any suitable system and / or method. Examples of suitable systems and methods for orienting the liner extension adapter 145 vertically and locking the extension liner adapter 145 in the vertical orientation are disclosed in U.S. Patent Application No. 61 / 482,132, filed on May 3, 2011 and entitled "Adjustment and Restriction System for a Flexible Submarine Connection", which is incorporated herein by reference in its entirety with all purposes.

Referring briefly to Figures 23-25, there is shown an embodiment of a system 300 for adjusting and restricting the angular orientation of the adapter of the casing extension 145 in relation to the base 144, the BOP 120 and the wellhead 130. In this exemplary embodiment, the system 300 includes a plurality of base members 301 circumferentially spaced around and mounted to the upper end of the base 144 and a plurality of the hydraulic cylinder assemblies 310, a cylinder assembly 310 radially positioned between each base member 301 and the extension pipe adapter 145. Each of the base members 301 includes a receptacle or upper cavity 302 within which a cylinder assembly 310 and a lower receptacle or cavity 303 are supported to receive the upper ends of the bolts and nuts 304 extending upwardly from the base 144.

Each of the hydraulic cylinder assemblies 310 includes a cylinder member 311 that rests on the upper receptacle 302 and a piston member 312 extending from the cylinder member 311. The piston member 312 is hydraulically actuated to extend or retract relative to the cylinder member 311. The piston member 312 includes a contact member 313 for engage the outer surface of the adapter of the casing extension 145.

When actuated, the piston member 312 can extend axially from the cylinder member 311 to exert a radial force on the adapter of the coating pipe extension 145 to pivot the adapter of the coating pipe extension 145 to the position vertical. In general, the hydraulic cylinder assembly 310 may be any one of several robustly rated cylinders, including, for example, the Enerpac® RC-502 hydraulic cylinders and / or the Enerpac® RC-504 hydraulic cylinders having a cylinder capacity of approximately 50 tons. Hydraulic cylinders with other different capacities and features are also contemplated and are known to one skilled in the art.

The base members 301 and the cylinder assemblies 310 are positioned around the adapter of the coating pipe extension 145 with one or more subsea ROVs (eg ROV 170). Specifically, the base members 301 and the cylinder assemblies 310 are positioned and circumferentially spaced to exert the appropriate radial forces on the adapter of the coating pipe extension 145 to vertically orient the adapter of the coating pipe extension 145 .

Referring now to Figure 26, there is shown an embodiment of another system 340 for adjusting and restricting orientation. of the extension pipe adapter 145 in relation to the base 144, the BOP 120 and the well head 130. In this exemplary embodiment, the system 340 includes a plurality of bolt covers 341 mounted to the upper ends of the bolts extending upwardly from the base 144 and a plurality of hydraulic cylinder assemblies 345 (only one cylinder assembly 345 is shown in Figure 26) positioned radially between the caps 341 and the adapter of the pipeline extension. lining 145. Each of the lids 341 is a rigid cylinder that includes a reamer or cavity at its lower end that receives the upper end of a bolt extending upwardly from the base 144.

Referring now to Figures 26 and 27, each of the hydraulic cylinder assemblies 345 includes a body 346 and a piston and cylinder assembly 347 coupled to the body 346. The body 346 includes a piston and cylinder housing 346a and a flange. 346b extending downward from the housing 346a. The piston and cylinder assembly 347 is disposed within the housing 346a and includes a piston member 348 hydraulically operated to extend or retract relative to the housing 346a. The piston member 348 includes a contact surface 348a for engaging the outer surface of the adapter of the coating pipe extension 145. A handle of the ROV 349 is coupled to the body 346 to facilitate the positioning of assembly 345 by an underwater ROV.

To adjust the angle between the pipe extension adapter 145 and the base 144, the covers 341 are mounted on the bolts extending upwardly from the base 144 and one or more assemblies 345 are arranged circumferentially around the base. Liner pipe extension adapter 145. Specifically, assemblies 345 are positioned radially between lids 341 and liner pipe extension adapter 145 with housing 346a engaging lids 341, piston member 348 which extends radially inwardly from the housing 346a towards the adapter of the coating pipe extension 145 and the flange 346b which meshes with the inner surface of the base 144. Then, the assemblies 347 are driven to extend the piston members 348 radially inward to mesh with the adapter of the casing extension 145. The action Continuous assembly of the assemblies 347 causes the piston members 348 to exert a radial force on the adapter of the coating pipe extension 145 to pivot the adapter of the coating pipe extension 145 to the desired vertical position. In general, the hydraulic cylinder assembly 345 can be any one of several robustly rated cylinders, including, for example, the Enerpac® RC-502 hydraulic cylinders and / or the Enerpac® RC-504 hydraulic cylinders having a cylinder capacity of approximately 50 tons. Hydraulic cylinders with other different capacities and features are also contemplated and are known to one skilled in the art.

The caps 341 and the cylinder assemblies 345 are positioned around the adapter of the coating pipe extension 145 with one or more subsea ROVs (e.g., ROV 170). Specifically, caps 341 and cylinder assemblies 345 are positioned and separated in circumferential fashion to exert the appropriate radial forces on the adapter of the coating pipe extension 145 to vertically orient the adapter of the coating pipe extension 145.

Once the adapter 145 is oriented vertically, it is preferably locked in the vertical orientation so that it does not bend or flex during or after the installation of a containment cover. For example, the systems 300, 400 may be uniformly disposed circumferentially around the adapter of the casing extension 145 to exert balanced radial forces which maintain the adapter of the casing extension 145 in the vertical orientation. Alternatively, rigid wedges may be provided on the ring positioned radially between the adapter of the extension of liner pipe 145 and base 144 and uniformly circumferentially spaced around the liner pipe extension adapter 145 once adapter 145 is vertically oriented to maintain adapter 145 in the vertical orientation.

Referring now to Figures 28 and 29, there is shown an embodiment of a group 350 of wedge members 360 for locking the adapter of the coating pipe extension 145 in a vertical orientation. The wedge members 360 are dimensioned and configured to be positioned in the ring between the adapter of the liner pipe extension 145 and the cylindrical base 144. Specifically, the wedge members 360 are numerically marked (e.g., "1", "2", "3", "4") to designate the circumferential order in which the wedge members 360 are arranged within the group 350. For example, the wedge member 360 marked "1" is circumferentially adjacent to the member of the wedge 360. wedge 360 marked "2", which is circumferentially adjacent to wedge member 360 marked "3", and so on. With the wedge members 360 arranged in the correct circumferential order, the group 350 defines an inner annular cylindrical surface 351 disposed in an inner diameter Di and an outer annular cylindrical surface 352 disposed in an outer diameter Do. The inner diameter Di is substantially equal to or slightly larger than the outer diameter of the adapter of the pipe extension of lining 145 and the outer diameter Do is substantially equal to or slightly smaller than the inner diameter of the base 144. Therefore, when the wedge members 360 are arranged in the proper circumferential order and arranged around the adapter of the pipe extension lining 145, the inner surface 351 is engaged with the liner pipe extension adapter 145 and the outer surface 352 engages the inner surface of the base 144, thereby locking the position and angle of the lug extension adapter. liner pipe 145 in relation to base 144. In this embodiment, a handle of ROV 361 engages each of wedge members 360 to facilitate independent positioning of wedge members 360 by an underwater ROV.

As best shown in Figure 29, the inner surface 351 is centered around a first center 351a and the outer surface 352 is centered around a second center 352a that is radially offset from the center 351a. the level of radial deflection of the centers 351a, 352a can be varied to orient and lock the adapter of the casing extension 145 at a particular angle relative to the base 144.

Referring now to Figures 30A-30P, it is shown that the containment cover 200 previously described is being deployed and installed under the sea on the flexible joint 143 of the LMRP. 140, after the liner extension adapter 145 has been prepared for engagement with the transition reel 330 as previously described, to contain and close the well 101. Since the receptacle 150b at the lower end 222b of the spool piece 222 is not configured or designed to engage and engage the flange 145a, the transition spool 330 previously described first unfolds and engages the LMRP 140, followed by the deployment and installation of the assemblies 210, 25, 290. In Figures 30A-30D, it is shown that the transition spool 330 is being lowered in a controllable way under the sea and is being secured to the flexible joint 143; in Figures 30E-30H, it is shown that the lower mount 210 is being lowered in a controllable way under the sea and is being secured to the transition spool 330; in Figures 30I-30L, it is shown that the upper mount 250 is being lowered in a controllable way under the sea and is being secured to the lower mount 210; and in Figures 30 -30P, it is shown that the death-countercurrent assembly is being lowered in a controllable way under the sea and the upper assembly 250 is being secured.

Referring first to Figure 30A, it is shown that the transition spool 330 is being lowered in a controllable way under the sea with the cable 181 and the cables 253 secured to the reel 330 and extending to a surface vessel. Due to the weight of the reel 330, the cable 181 and the cables 253 are of preference for relatively strong cables (eg steel cables) capable of withstanding anticipated tensile loads. Preferably a winch or crane mounted to a surface vessel is used to hold and lower the reel 330 on the cable 181. While the cable 181 is used to lower the reel 330 in this embodiment, in other embodiments, the reel 330 can be deployed under the sea with an operating tool mounted at the lower end of the pipe chain. Using the cable 181, the reel 330 is lowered under the sea under its own weight from a location generally up and laterally offset from the well 101, the BOP 120 and the LMRP 140 and out of the boom 160 to reduce the potential of the formation of hydrates inside the reel 330.

Turning now to Figure 30B, the spool 330 is lowered laterally offset from the adapter of the coating pipe extension 145 (outside the boom 160) until the shoe 340 is slightly above the flange 145a. When the reel 330 descends and approaches the adapter of the casing extension 145, the ROVs 170 monitor the position of the reel 330 relative to the flexible joint 143. Then, as shown in Figure 30C, the transition reel 330 moves laterally to the position immediately above the lining pipe extension adapter 145 with the shoe 340 substantially aligned coaxially with the lining pipe extension adapter 145. In addition, the spool 330 is rotated about the axis 335 to substantially align the guide pins 338 with the corresponding holes 148 in the flange 145a. One or more ROV 170 may use its hooks 172 to guide and rotate the spool 330 to the correct alignment with respect to the flange 145a.

Due to its own weight, the reel 330 is substantially vertical, while the adapter of the casing extension can be oriented at an angle in relation to the vertical line. Therefore, it should be understood that the perfect coaxial alignment of the shoe 340 and the flexible joint 143, as well as the perfect alignment of the pins 338 and the engagement holes in the flange 145a, can be difficult.

With the shoe 340 positioned immediately above and generally aligned coaxially with the pipeline extension adapter 145, and the guide pins 338 aligned with corresponding holes in the flange 145a, the wire 181 lowers the bottom spool 338 axially downward, thereby inserting and axially advancing the pins 338 into corresponding holes 148 and axially inserting and advancing the lower end of the shoe 330b into the adapter of the coating pipe extension 145 and the flange 334 is axially supported and meshed with the tab 145a as shown in Figure 30D. The frustoconical surface on the lower end of each of the pins 338 function to guide each of the pins 338 in the corresponding hole 148, even though the pins 338 are at first slightly misaligned with the holes 148. Similarly, the taper on the lower end 330b functions to guide the insertion and the coaxial alignment of the reel 330 and the adapter of the casing extension 145 when the reel 330 is lowered from a position immediately above the adapter of the casing extension 145, even though the shoe 340 is at first slightly misaligned with the liner extension adapter 145. During the installation of the reel 330, the emitted hydrocarbons run freely through the reel 330 and the slots 343 in the shoe 340, thereby relieving the pressure in the well and offering the potential to reduce the resistance to the axial insertion of the shoe 340 in the adapter of the prolo ng of casing pipe 145 and the coupling of transition spool 330 thereto.

With the shoe 340 resting sufficiently on the adapter of the casing extension 145 and the flange 334 which abuts the coupling flange 145a, the holes 334a are aligned coaxially with the corresponding holes 147 in the flange 145a and the plug 337 is disposed in the sludge intensification outlet 149b. Then, an ROV 170 cuts the band 336, thereby allowing the bolts 334b to fall into the holes 147. One or more ROV 170 may also contribute to facilitate the descent of bolts 334b in holes 147 if necessary. The bolts 334b can then be adjusted with the ROV 170 to rigidly secure the spool 330 to the pipeline extension adapter 145. With a secure, sealed connection between the spool 330 and the pipeline extension adapter 145, the ROV 170 uncouples the cables 253 from the transition spool 330. The cables 253 can then be removed to the surface with the cable 181.

Once the transition spool 330 is firmly coupled to the coating pipe extension adapter 145, the assemblies 210, 250, 290 are deployed in the same manner as previously described with respect to Figures 20A-20L with the exception of that the lower mount 210 is connected to the transition spool 220. Specifically, as shown in Figures 30E-30H, the lower mount 210 is lowered under the sea as previously described and is coupled to the transition spool 330 through the upwardly facing plug gear 150a of the transition spool 330 and the downward facing receptacle 150b of the bottom mount 210 to form a well-mouth type connection 150 therebetween. Then, as shown in Figures 30I-30L, the upper mount 250 is lowered under the sea and connected to the lower mount 210 as previously described and then, as shown in the Figures 30 -. 30 -30p, the counter-current death assembly 290 is lowered under the sea and connected to the upper assembly 250 as previously described. Well 101 can be contained and closed with assemblies 210, 250 (with or without using death fluids through assembly 290) in the same manner as previously described. It should also be appreciated that before the installation of the counter-current kill assembly 290, or after removal of the countercurrent killing assembly 290, the aligned perforations 224, 262 allow the re-entry of the LMRP 140, the BOP 120 and the well 101.

Once the well closes and is generally under control, and that the infrastructure needed to produce the well 101 is in place (for example, hydrocarbon storage vessels, liners, collectors, power lines are installed , etc), well 101 can be produced through countercurrent assembly 290 and / or conduit 235. In addition, injection systems 240, 270 can be used before, during, or after closure of well 101 to inject chemical compounds in the perforations 225, 262, respectively and the well 101. While Figures 30A-30P show that the containment cover 200 is being deployed and installed under the sea on the adapter of the coating pipe extension 145, the installation of the cover 200 on the LMRP 140, the mouth of the well 130, or the BOP 120 is made in the same way with the exception of the preparation of the support place (for example, the LMRP 140, the mouth of the well 130, or the BOP 120).

Referring now to Figure 31, another embodiment of a containment cover 400 is shown to cover the previously described well 101 (Figure 4) and to contain hydrocarbon liquids therein. The containment cap 400 is similar to the containment cap 200 previously described. That is, the containment cover 400 is modular and includes a first lower assembly 210 that was previously described. For clarity purposes, the frame 211, the second pipe reel 230, the chemical compound injection system 240 and the sensor system 226 of the lower mount 210 are not shown in Figure 31. Unlike the cover 200 previously described, in this embodiment , the upper assembly 250 and the death-countercurrent assembly 290 are not included. In contrast, the upper mount 250 has been replaced with a valve assembly 450 coaxially disposed in the main bore 224 of the lower mount 210, and the dead-countercurrent assembly 290 has been replaced with a cover 470. The valve assembly 450 is keep in removable form within the lower mount 210 by the lid 470. The lid 470 is firmly mounted to the lower mount 210 with an annular coupling member 480 that forms the type connections of the wellhead 150 with the lid 470 and the assembly bottom 210. Mounts 210, 450 work together to contain and close well 101, while lid 470 facilitates the delivery of dead-weight liquids to well 101 as well as the production of well 101 once it is contained and controlled.

As previously described, the lower mount 210 is suitable for air cargo. In this embodiment, the valve assembly 450, the cover 470 and the coupling 480 are also suitable for air cargo. Therefore, each of the lower mount 210, the valve assembly 450, the cover 470 and the coupling 480 is dimensioned and configured to be transported by air alone or with one or more of the assembly 210, the assembly 450, the cover 470 and coupling 480. In other words, each of the lower mounting 210, the valve assembly 450, the cover 470 and the coupling 480 has a weight and dimensions suitable for air transportation. In this embodiment, the valve assembly 450 has a weight of less than 30 tons and can therefore be transported together with the lower assembly 210.

Referring now to Figure 31, valve assembly 450 comprises a tubular body 451 having a central or longitudinal axis 452, a first upper end 451a, a second lower end 451b and a through bore 453 extending axially between the ends 451a, b. The assembly 450 also includes a pair of axially spaced valves 454 disposed along the through bore 453. The valves 454 control the flow of the liquids through the bore 453. That is, each of the valves 454 has a open position that allows the flow of liquids through it and a closed position that restricts and / or prevents the flow of liquids through it. The valves 454 are positioned in series along the through bore 453. Accordingly, the flow of liquids through the bore 453 is restricted and / or prevented if one or both of the valves 454 are closed and the flow of liquids a through perforation 453 is allowed if both valves 454 are open. In general, each of the valves 454 may comprise any type of valve suitable for anticipated liquid pressures and liquids in the bore 453 including, but not limited to, ball valves, gate valves and throttle valves. In addition, each of the valves 454 may be a manually operated, hydraulically actuated, mechanically driven or electrically operated valve. In this embodiment, each of the valves 454 is a hydraulically actuated ball valve qualified for a differential pressure of 15k psi. Each of the 454 valves can be controlled and operated under the sea with an ROV. Alternatively, each of the valves 454 can be controlled from the surface with hydraulic current lines or overhead wires extending from the surface engaging the valves 454 through a panel located on the lower mount 210.

The valve assembly 450 is partially arranged within the main bore 224, the upper end 451a is extends axially from the bore 224 and the lower end 451b is disposed in the bore 224. An annular insert 460 is coaxially disposed within the bore 224 axially between the mount 450 and an annular rim 224a within the bore 224. The insert 460 has a first upper end 460a, a second lower end 460b opposite the end 460a, and a current passage 461 extending axially between the ends 460a, b. The upper end 460a and the lower end 460b comprise a portion of reduced outer diameter that extends into the bore 224 below the flange 224a. Therefore, the insert 460 is supported in the perforation 224 against the rim 224a and the tubular body 451 is supported in the cavity 462. A plurality of annular seal assemblies 470 is disposed between the tubular body 451 and the spool piece 222 The seal assemblies 470 restrict and / or prevent liquids from flowing axially between the body 451 and the spool piece 222.

Referring still to Figure 31, cap 470 holds valve assembly 450 in bore 224 with lower end 451b supported on insert 460. Cap 470 is aligned coaxially with bores 224, 453 and has a first upper end 470a, a second lower end 470b and a current passage 471 extending axially between the ends 470a, b. In this embodiment, the upper end 470a comprises a current line connection that faces above 239a and lower end 470b comprises a downward facing plug 150a. A cavity or reamer 472 extends axially from the lower end 470b and defines an annular rim 473 in the passage 471. The tubular member 451 extends into the cavity 472 and is supported against the ridge 473. The ends 470b, 222a are supported and are held together with an annular coupling member 480. Specifically, the coupling member 480 is disposed around the ends 470b, 222a and includes an upward facing receptacle 250b releasably secured to the plug 150a at the end 470b to form a mouth-type type connection 150 therebetween and a downward-facing receptacle 150b releasably secured to the plug 150a at the end 222a to form a mouth-type-type connection 150 therebetween. The upwardly facing plug 239 a on the upper end 470a engages in a releasable manner and interlocks a coupling receptacle at the lower end of the current line to inject deadweight liquids into the cap 400 and the well 101 or produce Well 101 The containment cap 400 is deployed below the sea and is installed over the mouth of the well 130, the BOP 120, or the LMRP 140 to contain and close the well 101 and / or produce the well 101. To simplify the deployment, the lid containment 400 is preferably deployed and installed under the sea as a single unit in a single trip. In other words, in this embodiment, the valve assembly 450 is preferably installed in the lower mount 210, and the cover 470 is coupled to the lower mount 210 with the coupling 480 on the surface 102 and then the previously assembled complete cover 400 is lowered under the sea. To install the cover 400 on the BOP 120, the coating pipe extension 115 is removed from the LPR 140 and the LMRP 140 is removed from the BOP 120. Then, the cover 400 is lowered under the sea on a pipeline 180 or the cable 181 is coupled to the plug 239a and is firmly mounted to the BOP 120 with the mouth type connection of the well 150. To install the cover 400 in the mouth of the well 130, the extension of the casing 115 is removed from the LMRP 140, the LMRP 140 is removed from the BOP 120 and the BOP 120 is removed from the mouth of the well 130. Then, the cover 400 is lowered under the sea on a chain of pipes 180 or the cable 181 is coupled to the plug 239a, and it is mounted firmly to the mouth of the well 130 with the type connection of the mouth of the well 150. To install the lid 400 in the LMRP 140, the extension of the casing 115 is removed from the LMRP 140, then the transition reel 330 It is lowered under the sea and is firmly mounted to the extension adapter. coating pipe 145 as previously described. Then, the cap 400 is lowered under the sea and firmly assembled to the transition reel 150 with the mouth connection of the well 150. In each case, the cap 400 is preferably lowered below the sea laterally deflected from the well 101 and outside the boom 160 and then moves laterally on the support site (eg the BOP 120), the transition spool 330, or the mouth of the well 130) and is coupled to it with a type connection of the mouth of the well 150. One or more ROV 170 can be used to facilitate the installation of the cover 400 Although the cap 400 is preferably mounted on the surface 102 and then lowered under the sea as a single unit, and in other embodiments, the lower mount 210 and the valve assembly 450 can be lowered under the sea separately, and then mounted on the cover 400 under the sea. For example, the lower mount 210 can be lowered below the sea and can be installed over the mouth of the well 130, the BOP 120, or the transition spool 330 as previously described and then the valve assembly 450 can be lowered under the Sea with cable 181 or pipe string 180, install on bore 224 and secure assembly 210 with cover 470 and annular coupling 480.

Still referring to Figure 31, after the installation of the containment cap 400, the hydrocarbons are free to run through the cap 400. To contain and close the well, the valves 233 in the perforations 225, 232 and the valves 454 in bore 453 are manipulated by submarine ROVs 170. To use deadweight liquids in the closure of bore 101, a death liquid supply line is connected to plug 239a at upper end 470a of cap 470 before initiating the closing procedures. However, if the death fluids are not used to contribute to the closure of the Well 101, the closing procedures can be initiated before the installation of a power line on the 239a socket.

To close the well 101, both valves 233 in the current lines 237, 238 are closed and both valves 233 of the perforations 225, 232 are kept open while the upper valve 454 is kept closed. When the upper valve 454 transits to the closed position, the pressure of the well liquids within the lower assembly 210 is monitored by the pressure transducer 226 and the pressure of the well liquids within the upper assembly 250 is monitored by the sensor of the well. pressure 287. As long as the pressures of the forming liquids within the assemblies 210, 450 are within acceptable limits, the upper valve 454 remains closed until it is completely closed. Once the upper valve 454 is closed, the lower valve 454 can also be completely closed to provide redundancy. With both valves 454 closed, the liquid runs through the perforation 453 is restricted and / or prevented, although, since the valves 233 in the perforations 225, 232 open, the forming liquids are free to run through. the perforations 224, 225, 232, 236 and the throttle valve 234. Then, the valve 233 in the bore 232 transits to the closed position. When that valve 233 transitions to the closed position, the pressure of the well liquids within the lower assembly 210 is monitored with the pressure transducer 226. As long as the pressures of the formation liquids within assembly 210 are within acceptable limits, the drilling valve 233 232 remains closed until it is completely closed. Once the valve 233 of bore 232 is closed, the valve 233 of drilling 225 can also be completely closed to provide redundancy. With each valve 233, 454 closed, well 101 is contained and closed. Accordingly, in this embodiment, the valves 454 of the assembly 450 fulfill the same function (s) as the valves 263 of the upper assembly 250 described previously. It should be appreciated that the inclusion of the throttle valve 234 and the closing in stages of the well 101 through the consecutive closure of the valves 233, 454 allows a "soft" closure, thereby offering the potential to reduce the possibility of a inflow of abrupt formation pressure, which can damage the underwater components (for example, BOP 120, assembly 210, assembly 450, assembly 290) and lead to another underwater explosion.

Once well 101 closes and is generally under control, and that the infrastructure needed to produce well 101 is in place (for example, oil storage vessels, liners, collectors are installed , the power lines, etc), the well 101 can be produced through the plug 239 a at the upper end 470 a of the lid 470 and / or the duct 235. For example, according to the particular circumstances, the well 101 can produce through cap 470 with valves 233 closed and valves 454 open, can be produced through conduit 235 with valves 233 open and valves 54 closed or produced through both cap 470 and conduit 235 with all valves 233, 454 open.

As previously described, the bottom assembly 210 includes the chemical compound injection system 240. The injection systems 240 can be used before, during, or after the closure of the well 101 to inject chemical compounds into the perforations 224, 453, respectively and well 101. For example, chemical compounds such as glycol can be injected to reduce the hydrate formations within mounts 210, 450.

In the manner described, the embodiments of the containment caps described herein (for example, caps 200, 400) can be deployed under the sea from a surface vessel and installed over a submarine wellhead (e.g. well mouth 130), a BOP (eg, BOP 120) or an LMRP (eg, LMRP 140) that is emitting hydrocarbon liquids in the surrounding sea. Once it is firmly installed under the sea, a series of valves is activated and closed to achieve a "soft" closure of the well. Pressure and temperature sensors are included to measure the pressure and temperature of the well liquids, thereby enabling an operator manages the opening and closing of the valves in a manner that reduces the possibility of a burst while attempting to close the well. For example, while closing the well, the valves preferably close in a consecutive order while the well pressure is continuously monitored. In the event that the closing of a particular valve triggers an undesirable increase in the well pressure, that valve (or other valve) can be opened immediately to relieve the increased well pressure, thereby offering the potential to prevent a burst while the well closes. Similarly, after the well closes, the well pressure can be monitored so that a valve can be opened in the event of a point in the well pressure to relieve such an increase in well pressure.

Referring now to Figure 32, there is shown an overview of a method 500 for deploying and installing an embodiment of an underwater containment cover (e.g., containment cover 200, 400) over an underwater wellhead, a BOP , an L RP (for example, an LMRP chuck), or an adapter for the flexible joint liner extension that is emitting hydrocarbon liquids. Starting at block 501, an appropriate underwater support site is identified. In the embodiment of the marine system 100 previously described, the underwater BOP 120 is mounted to the wellbore 130 at the bottom of the sea 103 with a type connection of the mouth of the well 150, the LMRP 140 is mounted to the BOP 120 with the wellhead type connection 150, the flexible joint 143 is mounted to the LMRP 140 through the mandrel 151 and the coating pipe extension 115 is attached to the pipe extension adapter of coating 145 with a flange connection. Therefore, the potential support sites include the liner extension adapter 145 of the LMRP 140 after removal of the liner extension 115, the mandrel of the LMRP 115 after removal of the flexible joint 143, the BOP 120 after the removal of the LMRP 140 and the mouth of the well 130 after the removal of the BOP 120. These represent particularly suitable support sites since the various connections between these components can be uncoupled under the sea with the help of the ROV 170. The final selection of the most desirable support site can vary from one well to another and depends on a variety of factors including, but not limited to, the ease with which a particular connection can be broken and reconnected, the type of damage, the component (s) that is damaged (for example, BOP 120, LMRP 140, the extension of casing 115, etc), the potential for adverse effects when preparing the l selected support (for example, exposure of internal debris, trapped piping, etc.), the potential increased hydrocarbon / current emissions, the capacity of the support site and the associated hardware (for example, the BOP 120, the LMRP 140, etc.) to carry the load of the containment cover, or combinations of them.

If the selected support location is the mandrel 151 of the LMRP 140 or the extension pipe adapter 145, the connection between the coating pipe extension 115 and the coating pipe extension adapter 145 is broken and the pipe extension 5 The liner 115 is removed from the liner pipe extension adapter 145 according to block 506. If the selected lining location is the liner pipe extension adapter 145, then the appropriate transition spool (e.g. Transmission spool 330), as needed, is deployed and installed under the sea in accordance with block 510. However, if the support location is the mandrel of LMRP 151, then flexible joint 143 (which includes the liner extension adapter 145) is removed in block 535. Then, the appropriate transition spool (e.g., transition spool 330), as |15 necessary, it is deployed and installed under the sea on the mandrel 151 in the block 536. On the other hand, if the selected support location is the BOP 120, the extension of the lining pipe 115 is removed from the adapter of the pipe extension of liner 145, connection 150 between LMRP 140 and 20 BOP 120 is broken, and LMRP 140 is removed from BOP 120 in accordance with block 507. Furthermore, if the selected support location is the mouth of well 130 , the extension of casing 115 is removed from the adapter of the casing extension 145, the connection 150 between the LMRP 140 and the BOP 120 is broken, the LMRP 140 is removed from the BOP 120, the connection 150 between the BOP 120 and the mouth of the well 130 breaks and the BOP 120 is removed from the mouth of the well 130 according to block 508 .

It should be appreciated that the identification of the support location also influences whether a transition spool (eg, the transition spool 330) is necessary to attach the containment cap to the support location. For example, if the support site includes a connector or plug (e.g., plug 150a) configured to engage and engage receptacle 150b at lower end 222b, then a transitional spool is not necessary. On the other hand, if the support site comprises a connector or plug that is not configured to engage and engage the receptacle 150b at the lower end 222b, then a transition spool is necessary for the transition of the receptacle 150b at the lower end 222b to the particular type of connector or plug in the place of support.

Turning now to block 535, before, during or after the preparation of the support site according to blocks 506, 507, 508, the transition spool (for example, the transition spool 330) and the components of the cover containment (e.g., assemblies 210, 25, 290 of the containment cap 200, or assemblies 210, 450, the cap 470 and the coupling 480 of the containment cap 400 are transported to the location of maritime deployment. In general, the components of the transition spool and the containment cap can be transported by air to a suitable terrestrial stepped location and can be transported to the sea with a surface ship or vessel. The air transport of the transition spool and / or one or more of the components of the containment cap may be particularly desirable for transition spools and / or components stored or housed in a geographic location that is distant from the maritime deployment site. since long-range air transport is usually much faster than long-range maritime or land transport.

Once the transition spool (if necessary) and the containment cap assemblies 200, 400 have been transported to the maritime site, they can be deployed and installed under the sea to form the cover 200, 400 as previously described in block 520. Then, in block 525, well 101 is contained and closed with containment cap 200, 400 as previously described. With well 101 under control, countercurrent assembly 290 and / or conduit 235 can be used to produce well 101 according to block 530.

The previously described was an embodiment in which a particular transition spool 330 was employed to couple the containment cover 200 to the adapter of the coating pipe extension 145 of a particular flexible joint 143. Without However, manufacturers have developed numerous types of flexible liners for liners, liners for lower maritime liners, BOPs, and manholes. Specifically, there are numerous potentially different connector profiles through the flexible joints of the coating pipe extensions, the lower coating pipe extensions, BOP packages, and the manholes. As previously described, in some cases, the support site on the casing extension adapter, the LMRP, the BOP, or the wellhead may have a connector or plug with a profile designed to be directly engaged and engaged. with the receptacle 150b disposed at the lower end 222b. However, in other cases, the support location may have a connector or plug with a profile that is not compatible with a profile that is not compatible with the receptacle 150b at the lower end 222b. In each of the embodiments, a transition spool is used for the transition between the profile of the connector at the support location and the receptacle 150b at the lower end 222b. Accordingly, a variety of transition spools configured differently are needed for the transition between the receptacle 150b at the end 222b and the numerous connector profiles at the support location. This can best be explained with reference to Figure 33. As shown, the lower coating pipe extension pack 140 engages in removable to the BOP 120 which, in turn, is detachably coupled to the mouth of the well 130, as previously explained. In this example, five flexible joints of the different coating pipe extensions 143A-143E have lower connectors configured in an identical manner that are suitably configured for connection to the upper connection of the LMRP 140 (ie the mandrel 151), but each one has an adapter for the extension of the casing which extends upwards, configured differently 145A-145E, respectively, which, in the normal course of drilling and production, is coupled to a length of casing ( it is not shown in Figure 33). In the situation where it is desirable to attach a containment cover 200, 400 to one of the adapters of the coating pipe extensions 145A-145E, a transition spool configured differently in each case is needed.

More specifically, Figure 33 shows five adapters of the differently configured liner pipe extensions 145A-145E, each suitable for connection to a differently configured transition spool, shown as 330A-330E. It should be understood that the schematic representations of the adapter profiles of the coating pipe extensions 145A-145E do not represent real shapes or actual profiles of the adapters of the coating pipe extensions, but are used in the present only to show that that pipeline extension adapter 145A has a different configuration of the pipeline extension adapter 145B, which has a different configuration of the pipeline extension adapter 145C and so on. Having such profiles of the connectors with a different configuration requires that the transition reels 330A-330E have downwardly extending connectors and associated connector profiles that are different from one another such that they are configured to be detachably attached to the connector. Adapter of corresponding casing extension 145A-145E. While the lower end of each of the transition spools 330A-330E is different to accommodate an extension adapter with a different configuration 145A-145E, the upper end of each of the transition reels 330A-330E has the same configuration for the gear, in each case, with a containment cover of a uniform design. In this case, each of the transition reels 330? -330? includes a well-type plug connection 150a at its upper end configured to engage and engage the complementary female receptacle 150b at the lower end 222b of the lid 200, 400 to form a normal well-mouth type connection 150 .

Referring now to Figures 34 and 35, there is shown an embodiment of an adapter for the containment cap or reel of transition 600. In general, the transition spool 600 functions for the transition between the connector and the associated connector profile at the lower end of the containment cover (e.g., the female receptacle 150b at the end 222b) and the connection and the associated connector profile at the support site (for example, the pipeline extension adapter 145, the LMRP 151 mandrel, the 150a plug of the BOP 120, or the 150a socket of the wellbore 130). In this embodiment, the transition reel 600 includes an upper part or reel 610 and a lower part or reel 620 coupled to the upper reel 610. The upper reel 610 has a central axis 615, a first upper end 610a, and a second lower end 610b. In addition, the upper part 610 includes a connector 611 at the upper end 610a, an annular flange 613 at the lower end 610b and a tubular body 612 extending axially from the connector 611 to the flange 612. A through hole 614 extends axially through the reel 610 from the upper end 610a to the lower end 610b. The flange 613 includes an annular planar viewing surface 616 having an annular groove 617 and a plurality of circumferentially spaced holes 618 extending axially therethrough. The connector 611 at the upper end 610a is configured to engage and engage sealingly with the containment cap. Therefore, for connection to the containment cover 200, 400 previously described, the connector 611 is a plug 150a configured to couple and engaging the complementary receptacle 150b at the lower end 222b of the containment cap 200, 400.

The lower spool 620 has a central axis 625, a first upper end 620a, and a second lower end 620b. Further, the lower portion 620 includes an annular flange 621 at the upper end 620a, a connector 624 at the lower end 620b, a frusto-conical body 622 extending axially from the flange 621 and a tubular body 623 extending from the body 622 to the connector 624. A through hole 626 extends axially through the spool 620 from the upper end 620a to the lower end 620b. The tab 621 is configured in the same way as the tab 613 described previously. Specifically, flange 621 includes an annular planar viewing surface 627 having an annular groove (not shown) and a plurality of circumferentially spaced holes 629 extending axially therethrough. The connector 624 at the lower end 620b is configured to engage and engage sealingly with a complementary connector on the support location (for example, the adapter of the coating pipe extension 145, the mandrel of the LMRP 151, the BOP 120 , the mouth of the well 130). Due to the number of possible connectors across the different support locations, the connector 624 can comprise any one of numerous possible connectors described in more detail below. For the connection to a tab in the place of support, the connector 624 may comprise a coupling flange including alignment pins to facilitate alignment of the coupling flanges.

To connect the upper reel 610 to the lower reel 620, an annular seal 630 formed of inconel or other suitable material is positioned in the annular groove on facing surfaces 616, 627, the reels 610, 620 are aligned coaxially, and the flanges 613, 621 they are pushed into the gear with one another. With the holes 618, 629 aligned, the threaded bolts 631 and the hexagonal nuts 632 are clamped together to the upper and lower spools 610, 620.

Referring now to Figures 36A-36N, different configurations of adapters 600A-600N are shown. Each of the adapters 600A-600N includes an upper part 610 that was previously described and a lower part 620A-620N, respectively. Therefore, the same upper part 610 is used in each of the adapters 600A-600N, the upper part 610 includes the connector 611 configured to couple and mesh in a sealing manner the complementary connector on the containment cover (e.g. receptacle 150b at the lower end 222b of the containment cap 200, 400). In these embodiments, the connector 611 is a male H4 connector, available from Cameron International Corp, having a connector profile configured to engage and mesh with the receptacle complementary female 150b at the lower end 222b of the containment cap 200, 400, which is a female H4 connector, available from GE Oil & Gas from Houston, Texas. The tab 613 is an API tab of 46.87 cm. Each of the lower parts 620A-620L is the same as the lower spool 620 previously described with the exception that the connector 624A-624L, respectively, at each of the lower ends 620b is different to accommodate a different coupling connector 650A -650L, respectively, in the support place 651A-651L, respectively. The lower part 620M, 620N simply comprises a connector 624M, 624N, respectively, which is connected directly to the flange 613 of the upper part 610 with bolts. In other words, the 624M, 624N connectors do not include a frustoconical body 622 or tubular body 623 as previously described. The 624M, 624N connector is different to accommodate a different coupling connector 650M, 650N, respectively, at the support location 651M, 651N, respectively. In general, the connectors 650A-650L and the corresponding support sites 651A-651L described in more detail below are used on the pipeline extension adapters (for example, the adapter 145), while the 650M, 650N and the corresponding support places 651M, 651N are used on the LMRPs (for example, the LMRP 130), BOP (for example, the BOP 120) and the mouths of the well (for example, the mouth of the well 130). The tab 621 of each of the lower reels 620A-620L is configured to engage and engage the tab 613 and the upper end of each of the connectors 624M, 624N is configured to engage and engage the tab 613. Accordingly, since the tab 613 is an API tab of 46, 87 cm, the tab 621 of each of the lower reels 620A-620L is an API tab of 46, 87 cm coupling and the upper end of each of the connectors 624M, 624N is configured to be coupled with an API tab of 46.87 cm.

In Figure 36A, the connector 624A of the bottom 620A is a female CLIP® connector, available from Aker-Kvaerner, which has a connector profile configured to engage and engage in sealing with the complementary connector 650 A, which is a male CLIP® connector, available from Aker-Kvaerner. In Figure 36B, the connector 624B of the bottom 620B is a female Load King® connector, available from Cameron International Corp, which has a connector profile configured to engage and engage in sealing with the complementary connector 650B, which is a male Load King® connector, available from Cameron International Corp. In Figure 36C, the 624C connector on the bottom 620C is a male HME-F connector available from Veteo Gray, Inc., which has a connector profile configured to couple and engage in sealing with the complementary 650C connector, which is a female HME-F connector, available from Veteo Gray, Inc. In Figure 36D, the 624D connector on the bottom 620D is a male MR-6H connector, available on Veteo Gray, Inc., that has a connector profile configured to couple and mesh with the complementary connector 650D, which is a female R-6H connector available from Veteo Gray, Inc. In Figure 36E, the 624E connector on the bottom 620E is an MR-6C connector female, available from Veteo Gray, Inc., which has a connector profile configured to couple and mesh with the complementary 650E connector, which is a male MR-6C connector available from Veteo Gray, Inc. In Figure 36F, the 624F connector from the bottom 620F is a female MR-6D connector, available from Veteo Gray, Inc., which has a connector profile configured to couple and mesh with the complementary 650F connector, which is a male MR-6D connector available from Veteo Gray , Inc. In Figure 36G, the 624G connector on the bottom 620G is a male HMF-G connector, available from Veteo Gray, Inc., which has a connector profile configured to couple and engage with the 650G companion connector, which is a female HMF-G connector available from Veteo Gray, Inc. In Figure 36H, the 624H connector of the lower part 620H is a male HMF-D connector, available from Veteo Gray, Inc., which has a connector profile configured to couple and mesh with the complementary connector 650H, which is a female HMF-D connector available from Veteo Gray, Inc. In Figure 361, connector 6241 of bottom 6201 is a male HMF-E connector, available from Veteo Gray, Inc., having a connector profile configured to engage and mesh with complementary connector 6501, which is a female HMF-E connector available from Veteo Gray, Inc. In Figure 36J, the 624J connector from the bottom 620J is a female FT-GB connector, available from National Oilwell Vareo, Inc. of Houston, Texas, which has a connector profile configured to couple and engage with the 650J complementary connector, which is a male FT-GB connector available at National Oilwell Inc of Houston, Texas. In Figure 36K, the 624K connector of the bottom 620K is a male RD connector, available from Cameron International Corp., which has a connector profile configured to couple and engage with the complementary 650K connector, which is an available female RD connector. at Cameron International Corp. In Figure 36L, the 624L connector on the bottom 620L is a female DT-2 connector, available in Shafer, that has a connector profile configured to couple and engage with the 650L complementary connector, which is a DT-2 male connector available in Shafer. In Figure 36M, the 624M connector on the bottom 620M is a female SHD H4 connector, available from Cameron International Corp., which has a connector profile configured to couple and mesh with the 650M companion connector, which is a male SHD H4 connector Available at Cameron International Corp. In Figure 36N, the 624N connector on the bottom 620N is a female HC connector, available from Cameron International Corp., which has a connector profile configured to couple and mesh with the 650N companion connector, which is a male HC connector available from Cameron International Corp.

As will be understood then, a single lid can be used containment (eg, cap 200, 400) so that it closes and contains a well by placing the cap in any one of four locations (over the mouth of the well 130, over the BOP 120, over the mandrel 151 of the LMRP 140 , or on the extension pipe adapter 145). This can be achieved by maintaining an inventory of several transition reels 600, said transition reels 600 having identical upper portions 610 and different lower parts 620 to accommodate different support locations. As used herein, the term "inventory" when used as a noun means a set of goods that are in existence. Similarly, the term "inventory" when used as a verb and the phrase "maintain an inventory" mean keeping the set of goods in stock and ready for sale. For a given well, the connector profiles of the wellhead, the BOP, the LMRP mandrel and the casing extension adapter are all known in such a way that the correct transition reel (s) 600 can be keep on the surface vessel or the derrick, 110, or in a more distant storage facility. For example, a storage facility may be used to house and maintain one of each type of transition spool 600 that might be necessary for use with all wells in a given region, such as the Gulf of Mexico. The inventory would include, in addition to the appropriate transition rolls 600, at least one containment cap 200, 400 (preferably stored in its modular form). Yes a burst of the well would occur, the modular components of the containment cover, as well as the necessary transition spools, could be identified, selected from the inventory and shipped expeditiously to the well site to be used to plug the well.

With reference to Figure 37, a storage facility 700 is schematically represented and houses the lower assembly 210, the assembly 250 and the death-countercurrent assembly 290, each of which was previously described, in a condition to be boarding and mounting in the containment cap 200. An inventory of at least one of each of a plurality of the 600 adapters (eg, one or more of the adapters 600A-600N) is also maintained in the inventory within the storage facility 700. ) as it might be necessary to connect the containment cap 200 to any wellhead, BOP, LMRP chuck, or pipeline extension in the geographic region for which it is dedicated to serve storage facility 700. For each well in that geographic region, the type and configuration of the wellhead is known. , BOP, LMRP chuck and cladding extension adapter. In this example, the 600A-600F, 600M, and 600N adapters comprise all the adapters needed to mount the cover 200 to each of the wellhead, the BOP, the LMRP mandrel, and the extension pipe adapter. each well of the region. However, it should be noted that all combinations of 600A-600N adapters (or other transition spools that include different connectors) may be included in installation 700 according to the wellhead, BOP, LMRP mandrels and adapters stures. of pipeline extensions of the geographical region of interest. If an underwater burst occurs, information about the well and its sture (for example, the wellhead, the BOP, the LMRP mandrel and the casing extension adapter) is transmitted to the technical service personnel the equipment stored in storage facility 700. Alternatively, technical service personnel may have information available and be able to "search" for information on the type and configuration of all equipment in each well. Once the information is known, the appropriate adapter (s) 600 necessary (eg, necessary to connect the containment cover 200 to a specific well component or components) is selected and deployed for transport to the well site together with the containment cap assemblies 210, 250, 290 to cover and contain the well. Having modular retainer caps assemblies (eg, assemblies 210, 250, 290) and all possible adapters (eg, 600A-600F, 600M and 600N adapters) in stock and ready for shipment can provide a means of faster and more efficient to plug an underwater well and can decrease the impact and potential environmental damage. While the storage facility 700 shown in Figure 37 includes the components of the containment cap 200 (e.g., bottom mount 210, top mount 250 and dead-back assembly 290), in other embodiments, the installation of storage (for example, installation 700) can alternatively include the components of the containment cover 400 previously described (eg, bottom mount 210, valve assembly 450 and lid 470).

Referring now to Figure 38, another storage facility 800 is schematically represented and houses the lower mount 210, the upper mount 250 and the dead-back assembly 290 of the containment cap 200, each of which was previously described . In addition, an inventory is maintained in the installation 800 which includes at least one upper part 610 (two are shown in this example) and each of the lower parts 620A-620F, 620M and 620N of the adapters 600A-600F, 600M and 600N required for the technical service of the wells in the designated region. Again, it should be understood that the lower parts 620A-620F, 620M and 620N of the adapter 600A-600F, 600M and 600N, respectively. In general, all the combinations of the lower parts 620A-620N (or other lower parts including different connectors) can be included in the installation 800 according to the stures of the manhole, BOP, LMRP mandrels and the extensions adapters of coating pipes of the geographic region of interest. Because the upper portion 610 of each of the adapters 600A-600F, 600M, and 600N is identical in these embodiments, it is not necessary to inventory an upper portion 610 for each of the adapters 600A-600F, 600M, and 600N . On the other hand, in view of the need arising, the appropriate lower part 620A-620F, 620M and 620N can be selected and mounted to the upper part 610 that was previously described. While some additional time is needed to make this connection, it is one that does not take time openly and can save costs to manufacture, maintain and store multiple 610 tops for each of the 600A-600F, 600M and 600N adapters. While the storage facility 800 shown in Figure 38 includes the components of the containment cap 200 (e.g., the bottom mount 200, the top mount 250 and the kill-countercurrent assembly 290), in other embodiments, the storage facility (e.g., facility 800) may alternatively include the components of the containment cap 400 previously described (e.g., bottom mount 200, valve assembly 450 and lid 470).

While preferred embodiments have been shown and described, those skilled in the art can make modifications thereto without departing from the scope or teachings herein. The embodiments described herein are examples only and are not exhaustive. Many variations and modifications of the systems, apparatuses and processes described herein are possible and are within the scope of the invention. For example, the relative dimensions of various parts, the materials from which the various parts are made and other parameters may be varied. Accordingly, the scope of protection is not limited to the embodiments described herein, but is limited only by the following claims, the scope of which includes all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the steps of claiming the method can be performed in any order. The citation of identifiers such as (a), (b), (c) or (1), (2), (3) before the steps of claiming the method are not intended to specify and do not specify a particular order of the steps, but rather are used to simplify the subsequent reference to such steps.

Claims (17)

1. A method to control hydrocarbons that run from an underwater structure, comprising: lowering an adapter from the surface to an underwater structure, the adapter has a through hole that extends between an upper connector having a first connector profile and lower connector having a second connector profile that is different from the first connector profile; attach the lower connector of the adapter to the underwater structure; lower a containment cap from the surface to the adapter; Y Attach the containment cap to the upper connector of the adapter.
2. The method according to claim 1, further comprising: maintaining an inventory comprising a plurality of adapters, at least some of the plurality of adapters include an upper connector with a top connector profile configured to mate with the containment cap and a lower connector with a connector profile lower that is different from the upper connector profile and different from the lower connector profile of at least some of the other adapters.
3. The method according to claim 2, further comprising choosing from the inventory the adapter with the lower connector having the lower connector profile configured to be coupled with a connector on a resting place on the underwater structure.
4. The method according to claim 3, wherein the resting place is an adapter for the extension of the cladding pipe of a subsea flexible joint, a mandrel for a lower maritime cladding extension, a blowout preventer. or a wellhead.
5. The method according to claim 2, further comprising coupling the upper connector to the lower connector.
6. 6. The method according to claim 1, further comprising: maintaining an inventory comprising at least one upper connector and a plurality of lower connectors; wherein each of the upper connectors has a top connector profile configured to mate with the containment cover; wherein each of the lower connectors has a lower connector profile that is different from the upper connector profile and different from the lower connector profile of at least some of the other lower connectors.
7. A method to plug an underwater well comprising: choosing from an inventory of adapters a selected adapter, the selected adapter has a lower connector with a lower connector profile configured to mate with a connector on an underwater structure and an upper connector with an upper connector profile that is different from the connector profile lower; Y connect the lower connector of the selected adapter to the underwater structure.
8. 8. The method according to claim 7, further comprising attaching a containment cap to the upper connector of the selected adapter.
9. 9. The method according to claim 7, further comprising conducting a stream of hydrocarbons through the selected adapter.
10. The method according to claim 8, further comprising coupling the containment cap to the selected adapter while the hydrocarbons are running from the selected adapter to the containment cap.
11. The method according to claim 7, wherein the connection of the lower connector of the selected adapter to the underwater structure comprises connecting the lower connector of the selected adapter to the underwater pipe extension adapter, a submarine LMRP, a submarine BOP, or a mouth of the submarine well.
12. 12. A method to plug an underwater well, which includes: maintaining an inventory comprising a plurality of adapters, each of the plurality of adapters having an upper connector with an upper connector profile and an bottom connector of a lower connector profile that differs from the upper connector profile and also differs from the lower connector profile of at least some of the other adapters of the plurality; identify the connector profile of a submarine connector on an underwater structure in a well that is discharging hydrocarbons into the surrounding seawater; Select from the inventory a select adapter that has the lower connector with the lower connector profile that is configured to mate with the submarine connector.
13. The method according to claim 12, further comprising shipping the select adapter and the inventory containment cover to a ship arranged on the sea surface generally above the subsea well.
14. The method according to claim 13, further comprising coupling the select adapter to the submarine connector and coupling the containment cap to the adapter while hydrocarbons are being discharged from the underwater equipment.
15. An adapter for attaching a containment cover to an underwater structure, the adapter comprises: a first part having a central axis, a first end, a second end opposite the first end, and a through hole extending axially from the first end to the second end, wherein the first end comprises a first connector having a profile of the first connector; a second part having a central axis, a first end, a second end opposite the first end and a through bore extending axially from the first end to the second end, wherein the second end comprises a second connector having a profile of second connector that is different from the first connector profile.
16. 16. The adapter according to claim 16, wherein the second end of the first part comprises an annular flange which engages an annular flange at the first end of the second part.
17. 17. The adapter according to claim 16, wherein the first connector is configured to engage and engage the connector of the underwater containment cap. The adapter according to claim 18, wherein the second connector is configured to engage and engage a connector on the subsea structure. An apparatus for controlling a subsea well, comprising: a containment cap having a through hole and a valve adapted to close and impede the flow of liquid through the through hole and further comprising a connector at the lower end of the well. containment cap having a first connector profile; an adapter comprising: an upper end and a lower end and a through bore extending between them; a first connector at the upper end coupled and meshed in sealing manner with the connector of the containment cap; a second connector at the lower end adapted to engage and engage sealingly with a connector on a submarine structure different from the containment cap, the second connector of the adapter has a second connector profile that is different from the profile of the first connector.