Oilfield equipment

(54) Title: EQUIPMENT FOR OIL FIELDS (73) Holder: WEATHERFORD TECHNOLOGY HOLDINGS, LLC. Address: 2000 St. James Place, Houston, Texas, UNITED STATES OF AMERICA (US), 77056 (72) Inventor: HANNEGAN, DON M.

Validity Term: 10 (ten) years from 12/04/2018, subject to legal conditions

Issued on: 12/04/2018

Digitally signed by:

Liane Elizabeth Caldeira Lage

Director of Patents, Computer Programs and Topographies of Integrated Circuits

G-άά.

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EQUIPMENT FOR PETROLEUM FIELDS _ / y

This request claims priority to the US patent application% sjJí: no. 11 / 975,554, which is incorporated by reference.

This invention relates to the field of equipment for oil fields. The embodiments of the invention relate to a system and method for converting a conventional annular emergency shut-off valve (BOP) between a non-pressurized mud return system and a pressurized mud return system for drilling with controlled pressure or for unbalanced drilling.

Marine tubes extending from the top of the well on the seabed have traditionally been used to circulate the drilled fluid back to a drilling structure or on a mast between the drill cable and the inner diameter of the tubes. The tube must be large enough in the inside diameter to accommodate the largest probe cable that will be used to drill. For example, tubes with internal diameters of 19% inches (49.5 cm) were used, although other diameters can be used. An example of a marine tube and some of the associated drilling components, as shown here in FIGS. 1 and 2 are proposed by U.S. Patent number

4.626.135.

The marine tube is generally not used as a pressurized containment vessel during conventional drilling operations. The pressures contained by the tube are generally the hydrostatic pressure generated by the density of the perforated liquid or the mud trapped in the tube and the pressure developed by pumping the fluid into the borehole. However, some well-developed wells are considered economically non-drillable

2/30 using conventional drilling operations. In fact, studies sponsored by the U.S. Department of the Interior, the Minerals Administration Service and the American Petroleum Institute, concluded that between 25% and 33% of all undeveloped reservoirs are not perforable using the methods conventional drilling systems, due, in large part, to the greater probability of controlling problems such as difficulty in differential ejection, lost circulation and sudden escapes.

Drilling hazards such as gas and abnormally pressurized aquifer areas in relatively the same mud line present challenges when drilling the top of many prospects, both in shallow and deep water. The danger of shallow gas is that it can be sweet or acidic and, if found, can reach the drilling deck very quickly. Surface ejections occur due to the lack of time on the equipment's safety valves (BOP). If acidic, even the amounts of traces of such exhaust gases constitute health, safety and environmental (HSE) risks, as they are harmful to humans and the environment. There are US and Canadian legal restrictions on the maximum amount of exposure to such gases, which can be borne by workers. For example, the Labor Safety and Health Administration (OSHA) establishes a daily limit of eight hours of exposure to traces of H2S gas if they do not use a gas mask.

The reduction in pore pressure and narrow drilling windows, due to small margins between forming pressure and open hole fracture pressure, as well as an increasing demand for deep water drilling and higher drilling costs indicate that the amount of reservoirs

3/30 known, considered economically impossible to drill with conventional drilling operations will continue to increase. New and improved techniques, such as controlled pressure drilling and improved drilling, such as pressure controlled drilling and underbalanced drilling, have been used successfully around the world in certain continental platform drilling environments. Controlled pressure drilling was recently approved in the Gulf of Mexico by the U.S. Department of the Interior, the Gulf of Mexico Minerals Management Service. Pressure-controlled drilling is an adaptive drilling process that does not bring hydrocarbons to the surface during drilling. Its main purpose is to more accurately manage the pressure profile of the well while maintaining the equivalent weight of the mud above the formation pressure at all times, either circulating or closed to make the articulated connections of the tubes. To stay inside the drilling window at a greater depth with the current mud, drill a deeper hole to eliminate the need for another drill string, the goal may be to safely drill in balance, or with greater balance or by applying back pressure from surface to obtain a higher equivalent mud weight (EMW) than the hydrostatic drop of the drilling liquid. Drilling below equilibrium is drilling with the hydrostatic drop of the drilling fluid and the equivalent weight of the mud when circulating, designed to be lower than the pressure of the formations being drilled. The hydrostatic drop in the fluid can naturally be less than pressure build-up or can be induced.

These new and improved techniques require pressure management devices, such as rotating control heads or

4/30 devices (referred to as RCDs) and rotary marine diverters. The RCDs, similar to this disclosed in U.S. Patent No. 5,662,181, provided a seal between a rotating tubular and the marine tube for purposes of controlling pressure or fluid flow to the surface at the same time as drilling operations are being conducted. Typically, an inner part or member of the RCD has been designed to seal around the rotating tubular and rotate with the tubular using the inner sealing element (s) and bearings. Additionally, the inside of the RCD allows the tubular to move axially and slide through the RCD. The term “tubular” as used here means all forms of drill pipe, tubing, boxes, drill rims, linings and other tubulars for operations in oil fields as understood in accordance with art.

US patent number 6,913,092 B2 proposes a seal box that includes an RCD positioned above sea level on the top section of the marine tube to facilitate a mechanically controlled and closed pressurized system, which is useful in sub-balanced underwater drilling. A tool that operates internally is proposed to position the RCD sealing box on the tube and facilitates its attachment to it. A remotely controlled external disconnect / connection clamp is proposed to hydraulically secure the RCD bearing and seal assembly to the seal case.

It is also known to use a double density fluid system to control the formations exposed in the open drilled hole. See the Feasibility Study for a Dual Density Mud System for Deepwater Drilling Operations by Clovis A. Lopes and Adam T. Bourgoyne, Jr., ©

1997 Offshore Technology Conference. As a high density sludge is

5/30 circulated to the tube, the 1997 study proposes to inject the gas into the mud column in the tube on the platform or close to the ocean platform to reduce the density of the mud. However, the hydrostatic control of the formation pressure must be maintained by a weighted mud system, that is, not cut by gas, below the seabed.

US Patent number 6,470,975 B1 proposes to position a piece of the inner box connected to an RCD below sea level with a marine tube using an annular explosion preventer (“BOP) with a marine diverter, and whose example is shown in the patent No. 4,626,135 discussed above.

The part of the inner box must be retained in the desired position by closing the annular seal of the BOP, so that a seal is provided between the part of the inner box and the inner diameter of the tube. The RCD can be used for under-balanced drilling, a double density fluid system, or other drilling technique that requires pressure to be contained. It is proposed that the inner part of the box should pass through the tube through a standard probe rim or a stabilizer.

US Patent number 7,159,669 B2 proposes that the RCD retained by the inner part of the box be self-lubricating. The proposed RCD is similar to the 7875 RCD model from Weatherford-Williams, available from Weatherford International, Inc. in Houston, Texas.

US Patent number 6,138,774 proposes a pressure box assembly that contains an RCD and an adjustable constant pressure regulator, positioned on the ocean floor above the spring to drill at least the initial portion of the well with only sea water and without a marine tube.

Publication No. 2006/0108119 A1 from the USA proposes a remote piston-activated locking assembly to lock and seal an RCD

6/30 with the top section of a marine tube or a bell-shaped nozzle positioned on the tube. As shown in FIG. 2 of publication 119, a single locking assembly is proposed, whereby the locking assembly is attached to the pipe or bell-shaped nozzle to lock an RCD with the pipe. As shown in FIG. 3 of publication 119, a double locking assembly is also proposed, in which the locking assembly itself can be attached to the bell-shaped tube or nozzle using a hydraulic piston mechanism.

US publication No. 2006/0144622 A1 proposes a system for cooling the radial seals and bearings of an RCD. As shown in FIG. 2A of publication 622, hydraulic fluid is proposed to lubricate a plurality of bearings and to energize an annular balloon to provide an active seal that expands radially inward, sealing around the tubular, like a drill string.

Marine BOP diverters are used in conventional hydrostatic pressure drilling when drilling platforms or structures. Manufacturers of marine BOP diverters include Hydril Company, Vetco Gray, Inc., Cameron, Inc., and Dril-Quip, Inc., all of Houston, Texas. When the BOP diverter seals are closed over the drill string, the liquid is safely diverted away from the drill deck. However, drilling operations must cease because the movement of the drill string will damage or destroy non-rotating annular seals. During normal operations, the diverter seals are open. There are a number of offshore drilling conditions, unrelated to well control, where it would be advantageous to rotate and move the drilling column inside a marine diverter with closed seals. Two examples are: 1) slow rotation to prevent the column from

7/30 drilling paralyzes when circulating the gas from the tube to what was in deep wells can take many hours and 2) suspend the drill column out of the bottom to minimize annular friction pressure after circulating the gas from the tube out, and before restarting drilling operations. Being able to drill with a closed seal will also allow you to drill ahead with a controlled back pressure applied to the ring while maintaining a more accurately drilled well pressure profile.

A marine diverter converter box for positioning with an RCD, as shown in FIG. 3 has been used in the recent past. However, the box must match the internal profile of one of the many models of marine BOP diverters, some of which are disclosed above, in which it is used. In addition, the elastomer annular seal and hydraulically activated piston must be removed before the converter housing is positioned there.

The US patents discussed above, numbered 4,626,135; 5,662,181;

6,138,774; 6,470,975 B1; 6,913,092 B2; and 7,159,669 B2; and US Publications numbers 2006/0108119 A1 and 2006/0144622 A1 are hereby incorporated by reference for all purposes together. With the exception of the '135 patent, all the aforementioned patents and publications have been assigned to the assignee of this invention. The 135th patent was granted to the Hydril Company of Houston, Texas.

While the drilling columns are usually equipped with a marine BOP diverter, used in conventional hydrostatic pressure drilling, the current inventor has evaluated a system and method for efficiently and safely converting annular marine BOP diverters between conventional drilling and pressure drilling controlled or balanced sub8 / 30 drilling. The system and method would allow conversion between a conventional annular marine BOP diverter and a rotary marine diverter. The inventor also assessed that it would be desirable for the system and the method that they would require minimal human intervention, especially in the well area and provide an efficient and safe method for positioning and removing the equipment. He also considered that it would be desirable for the system to be compatible with a number of different types and sizes of RCDs and annular marine BOP diverters.

One or more aspects of the invention are set out in the independent claim (s).

A system and method are disclosed to convert a diverter

Annular marine BOP used in conventional hydrostatic pressure drilling and a rotary marine diverter, which uses a rotary control device for controlled pressure drilling and under-balanced drilling. The rotary control device can be secured or locked with a universal marine diverter (UMDC) converter box. The UMDC box has an upper section and a lower section, with a threaded connection between them, which allows the UMDC box to be configured to the desired size and type of the annular marine BOP diverter box. The UMDC box can be positioned with a hydraulic tool so that its lower part can be positioned with the marine annular BOP diverter.

Some preferred embodiments of the invention will now be described, by way of example only and with reference to the accompanying drawings, in which:

FIG. 1 is an elevated view of an example of incorporating a semi-submersible floating drill rig showing a BOP of drawers

9/30 on the seabed, a marine tube, a subsurface annular marine BOP diverter and a surface diverter above.

FIG. 2 is an exemplary incorporation of a probe with a fixed lifter and with the BOP of drawers and a diverter above the water surface.

FIG. 3 is an elevated sectional view with an RCD attached to a marine diverter converter housing, the housing of which has been attached to an exemplary embodiment of an annular marine BOP diverter housing shown in the section without the elastomer annular plug seal and pistons .

FIG. 4 is an elevated sectional view of an RCD attached to a 10 UMDC box of an embodiment of this invention, whose UMDC has been positioned in an exemplary embodiment of a cylindrical marine diverter housing, which has a conventional elastomer plug annular seal.

FIG. 5 is an elevated sectional view of an RCD attached to a UMDC box of an embodiment of this invention, whose UMDC has been positioned in an exemplary embodiment of a cylindrical marine diverter housing, which has an annular elastomer shutter annular seal.

FIG. 5A is an elevated cross-sectional view of an RCD attached to a UMDC box of an embodiment of this invention, whose UMDC has been positioned in an exemplary embodiment of a cylindrical marine diverter housing that has a conventional elastomer plug annular seal.

FIG. 6 is a view similar to that of FIG. 4, unless with a split view showing the right side of the vertical axis of the conventional elastomer annular plug seal, coupling a conventional active inflatable elastomer annular seal, and on the right side of the conventional annular plug seal which further compresses the seal inflatable ring elastomer.

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FIG. 7 is a view similar to that of FIG. 4, except with the annular elastomer plug seal removed, and an active inflatable annular seal installed.

FIG. 8 is an enlarged elevated view of the interface section of an elastomer seal with the uneven surface of the UMDC metal housing of an embodiment of this invention.

FIG. 9 is an enlarged view of the elevation of the section of an elastomer layer between the elastomer seal and a regular metal surface of the UMDC housing.

FIG. 10 is an enlarged view of the elevation of the section of an elastomer layer between the elastomer seal and an irregular metal surface of the UMDC housing.

Generally, the embodiments of this invention involve a system and method for converting between an annular marine BOP diverter (FD, D) used in a conventional open, non-pressurized mud return system for drilling with hydrostatic pressure, and a rotary marine diverter, used in a closed and pressurized mud return system for drilling with controlled or under-balanced pressure, using a universal marine diverter (UMDC) converter box, generally indicated as 24, 24A, 24B, 24C and 24D in FIGS. 4-7, secured (FIGS. 4, 5A, 6 and 7) or locked (FIG. 5) with an RCD (7, 10,

100). Each illustrated UMDC box (24, 24A, 24B, 24C, 24D) has an upper section (3, 26, 104) and a lower section (2, 28, 50, 66, 106), with a screw connection (30, 86, 114) between them, which allows the UMDC box (24, 24A, 24B, 24C, 24D) to be easily configured to the size and type of the annular marine BOP diverter (FD, D) and the desired RCD (7 , 10, 100). It is contemplated that several lower sections of the box (2, 28, 50, 66, 106) that match the diverters

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Annular marine BOPs (FD, D) can be stored in the drilling rigs, as shown in FIGS. 1 and 2. The UMDC box (24, 24A, 24B, 24C, 24D) can be fixed in different sizes and types of marine BOP diverter boxes (38, 60, 70, 80, 118) using different configurations of conventional seals elastomer (42, 43, 64, 120), as will be discussed in detail below. It is contemplated that the UMDC box (24, 24A, 24B, 24C, 24D) will be made of steel, although other materials can be used. Examples of RCDs (7, 10, 100) are disclosed in U.S. Patent numbers 5,662,181, 6,470,975 B1 and 7,159,669 B2, and are commercially available as Weatherford-Williams models 7875 and 7900 from Weatherford International, Inc Houston, Texas.

Prior art drilling rigs or structures are generally indicated as FS and S, as shown in FIGS. 1 and 2. A semi-submersible floating offshore FS probe is shown in FIG. 1, and a self-elevating platform S is shown in FIG. 2, other drill rig configurations and embodiments are contemplated for use with this invention for offshore and onshore drilling. For example, the present invention is also applicable to drilling rigs such as semi-submersibles, submersibles, drilling vessels, boat platforms, platform rigs, and land rigs. With reference to FIG. 1, we have an exemplary incorporation of an FS drilling rig. A FB of the drawer BOP is positioned on the ocean floor above the FW of the wellhead. Conventional KL obstruction CL lines shown for control of the well between the drill rig FS and the drawer BOP FB.

A marine FR tube extends between the top of the BOP FB of the drawers and the

OB from the outer barrel of a high pressure lapse or a telescopic joint SJ

12/30 located above the water surface with a GH from the annular BOP of the gas manipulator between them. The SJ joint can be used to compensate for the relative movement of the drill rig FS to the FR tube when the drill rig FS is used in conventional drilling. An FD marine BOP diverter is attached to the inner barrel IB of the SJ joint under the drilling platform or FF soil. T tension support lines connected to a crane and pulley system on the FS drilling rig support the upper part of the FR tube. FIG. 2 does not illustrate a joint SJ, as the tube S is fixed. However, the BOP of drawers B is positioned above the water surface in the well area under the drilling platform or floor F.

In FIG. 3, a prior art marine diverter converter box H is secured with a cylindrical marine box 22 after removing the annular elastomer plug and hydraulically actuated piston seal. Sealing insert 20 seals the converter housing of marine diverter H with a cylindrical marine box 22. RCD 10 is attached to box H by the CL radial clamp. The tubular drilling column 12 is introduced through the RCD 10 so that the joint 13 supports the RCD 10 and its H box by the RCD under the rubber of the separator 14 while the RCD 10 enters the marine box 22. As is now understood, the prior art marine diverter converter box H would be built to serve in marine boxes from different manufacturers 22. In addition, the prior art H diverter converter housing requires that the elastomer annular plug seal and the hydraulically actuated piston be removed prior to installation.

FIG. 4 shows an embodiment of a UMDC box 24 of this invention, which has an upper section 26 and a lower section 28. A lower section

Box 13/30 includes a circumferential flange 32, a cylindrical insert 34, and a turning ring or support piece 37. The top box section 26 is threaded with the bottom 28 at the 30 screw connection. support part 37 is threaded with the cylindrical insert 34 in the screw connection 31. The threaded connection 31 allows both support pieces with a different outside diameter 37 to be positioned in the same cylindrical insert 34 and an elastomer sleeve to be received in the insert 34, as will be discussed in more detail below. It is contemplated that the threaded connection 31 may use an inverted (left) thread that tightens in the direction of rotation of the tubular columns 12 to drill. It is also contemplated that the screw connection 30 can use conventional threads on the right side. It is also contemplated that there may be no threaded connection 31, so that the cylindrical insert 34 and the support part 37 are integral. One or more anti-rotation pins 8 can be placed through aligned openings in the screw connection 30 after the upper sections 26 and lower 28 are connected with threads to ensure that the connection 30 does not loosen, as when the drill rig is suspended above from the bottom and the twisted drill column returns to equilibrium.

The RCD 10 can be radially secured with the clamp 16 to the upper section 26. The RCD 10 has a lower rubber seal 14 and an upper rubber seal, which is not shown, but arranged in pot 10. It should be understood that the different types of RCDs (7, 10, 100) can be used with all embodiments of the UMDC box (24, 24A, 24B, 24C, 24D) shown in FIGS. 4-7, including RCDs (7, 10, 100) with a single separating rubber seal, or double rubber seals with passive or active seals. O

Seal 14/30 seals the AB ring between the drill pipe 12 tubing and the UMDC housing (24, 24A, 24B, 24C, 24D). The clamp 16 can be manual, hydraulic, pneumatic, mechanical, or other form of remotely operated clamping means. The flange 32 of the bottom 28 of the UMDC box 24 can rest on the marine box 38, and be sealed with a radial seal 9. The outer diameter of the flange 32, like the flanges (1, 58, 76, 116) in FIGS . 5-7 is smaller than the typical internal diameter of 49% inches (1.26 m) of a rotary table on the offshore platform. Marine box 38, like marine boxes (60, 70, 80, 118) in FIGS. 5-7 may vary in the size of the inner diameter, such as 30 inches (76 cm) or

36 inches (91.4 cm). It is contemplated that the outer diameter of the flange 32 may be larger than the outer diameter of the marine box 38, and that flange 32 may extend outwards or be suspended over the marine box 38. For example, it is contemplated that the diameter outer flange 32, like the flanges (1, 58, 76, 116) in FIGS. 5-7 can be 48 inches (1.2 m) or at least less than the inside diameter of the probe turntable. However, other sizes of diameter are also contemplated. It is also contemplated that the flange 32 can be positioned on a row of screws that are typical in many designs of marine diverters D to secure the upper parts to the respective boxes. It is contemplated that the upper part of the marine carcass 38 does not need to be removed, although it can be removed if desired.

Continuing with FIG. 4, the UMDC box 24 can be positioned with the marine box 38 with an elastomer annular plug sealant 43 of the marine BOP diverter, as described in U.S. Patent number 4,626,135, whose elastomer annular plug sealant 43 is moved by the annular pistons P.

The annular seal 43 compresses the cylindrical insert 34 and seals the annular space A

15/30 between the cylindrical insert 34 and the marine diverter housing 38. Although an elastomer 43 annular plug seal is shown, other conventional active and passive seal configurations are contemplated, as discussed below. If an elastomeric seal, such as sealant 43 is used, the housing of the

UMDC 24 can be configured as shown in FIGS. 2, 5 and 6 of U.S. Patent No. 6,470,975 B1. It is also contemplated that a mechanical plug seal, as known to those skilled in the art, can be used. The outlets (39, 40) in the marine diverter housing 38 allow the flow of the perforated fluid to return when the pistons P are raised as shown in

FIG. 4, as discussed in detail below.

A layer of elastomer or liner 35 can be extended or placed radially on the outer surface of the cylindrical insert 34 so that the annular plug seal of elastomer 43 engages layer 35. The support piece 37 can be removed from the cylindrical insert 34. Also it is contemplated that the layer 35 can be a wrap, a sleeve, a mold, or a tube that can be slid over the cylindrical insert 34 when the support piece 37 is removed. Layer 35 can be used with any embodiment of the UMDC box (24, 24A, 24B, 24C, 24D) of this invention. Other materials besides the elastomer are contemplated for the layer 35 that similarly would seal and / or fasten. It is contemplated that solvent-resistant materials can be used, for example, nitrile or polyurethane. It is also contemplated that materials that are relatively soft and amenable to compression with a low durometer can be used. It is also contemplated that materials with a high temperature resistance can be used. Layer 35 seals and tightens with the 43 elastomer annular plug seal, or such other annular seal

16/30 as used, including conventional active inflatable seals (42, 64), as discussed in detail below. It is contemplated that the elastomer layer 35 may have an inch thickness (1.3 cm), although other thicknesses are also contemplated and may be desired when using different materials. Such layer 35 is particularly useful for preventing slippage and for sealing when an elastomer seal, when an elastomer plug seal 43 is used, as the contact surface area between seal 43 and insert 34 or layer 35 is relatively small, such as eight to ten inches (20.3 to 25.4 cm). It is further contemplated that an adhesive can be used to retain the wrap, the sleeve, the mold, or the layer of the tube 35 in the position on the cylindrical insert 34. It is also contemplated that the layer 35 can be a spray coating. It is contemplated that the surface of layer 35 may be sandy or uneven to increase its holding capacity. It is also contemplated that layer 35 can be vulcanized. The inner diameter 36 of the cylindrical insert 34 and / or the support piece 37 varies in size, depending on the diameter of the marine box 38. It is contemplated that the inner diameter 36 can be from eleven inches to thirty-six inches (27.9 to 91.4 cm), with the twenty-five inches (63.5 cm) of typical internal diameter. However, other diameters and sizes are contemplated, as well as different configurations are mentioned here.

FIG. 5 shows a UMDC box 24A of this invention, which has an upper section 3 and a lower section 2. The upper section 3 is shown as a box receiving a set of double latches 6. The lower section of box 2 includes the flange circumferential 1, the cylindrical insert 88, and the support piece or the turning ring 90. The upper section of the box 3 is connected by threads with the

17/30 lower section 2 on the screw connection 86, which allows the lower section 2 to be dimensioned for the desired marine box 80 and the upper section 3 has been dimensioned for the RCD 7 to be connected. The support piece 90 is threaded with the lower cylindrical insert 88 in the screw connection 92. Threaded connection 92 allows retaining parts with a different outside diameter to be positioned in the same cylindrical insert 88 and / or to receive layer 35 thereafter, as discussed above. It is contemplated that the threaded connection 92 can use an inverted thread (left) that tightens in the direction of rotation of the tubular columns of the drilling column to drill. It is also contemplated that the threaded connection 86 can use conventional threads on the right side. It is also contemplated that there may be no threaded connections (86, 92) if the upper section 3 and the lower section 2 are integral. One or more anti-rotation pins 84 can be placed through aligned openings in the screw connection 86 after the upper sections 3 and lower 2 are connected with threads to ensure that the connection 86 does not loosen, as discussed above, when the drilling rig 12 is suspended above the bottom.

As shown in FIG. 5, RCD 7 can be locked with a double set of locks 6, as proposed in U.S. Publication No. 2006/0108119 A1 and shown in FIG. 3 of publication 119. The formation of the radial lock or the retaining part 4 can be positioned in the radial groove 94 of the upper housing section 3, using a hydraulic piston mechanism. The formation of the radial lock or the retaining part 5 can be positioned in the radial groove 96 of the RCD 7, using a hydraulic piston mechanism. The double locking assembly 6 can be manual, mechanical, hydraulic, pneumatic or other form of mechanically operated locking means. It is also contemplated that a single set of

18/30 locking, as proposed in U.S. Publication No. 2006/0108119 A1 and shown in FIG. 2 of publication 119, can be used instead of the double locking set 6. It is contemplated that this single locking set can be attached to the upper section of box 3, for example, by screwing or welding, or it can be manufactured as part of the top section of box 3. As can now be understood, a locking set, such as set 6, allows the RCD 7 to be moved in and out of the UMDC 24A box, such as checking conditions or replacing the rubber seal separator 14, when time is of the essence.

While RCD 7 has only one rubber separating seal 14 (and no rubber separating seal), it should be understood that different types of RCDs (7, 10, 100) can be positioned in the UMDC box 24A, including RCDs ( 7, 10, 100) with double rubber separating seals with both passive and active seals. Seal 14 seals the AB ring between the drill pipe tubing 12 and the UMDC housing (24, 24A, 24B, 24C, 24D). Flange 1 of the lower section 2 of the UMDC 24A housing can rest on marine housing 80, and can be sealed with radial seals 82. It is contemplated that flange 1 may be suspended over the outer diameter of marine housing 80. The UMDC box can be positioned with the marine box 80 with a conventional elastomer annular plug seal 43 of the marine BOP diverter, as described in U.S. Patent No. 4,626,135, whose elastomer annular plug seal 43 is moved by the annular pistons Ρ. The annular seal 43 compresses the cylindrical insert 88 and seals the annular space A between the cylindrical insert 88 and the marine diverter housing 80. Although an elastomer 43 annular plug seal is shown, other conventional seal configurations

19/30 active and passive are contemplated, as discussed below. The UMDC box 24A of FIG. 5 can be positioned with the marine box 80 using the incorporations of a conventional inflatable annular elastomer seal (42, 64) shown in FIGS. 6-7, or the incorporation of a conventional annular elastomer seal 120 as shown in FIG. 5A. If an elastomeric seal, such as seal 43 is used, the UMDC 24A housing can be configured as shown in FIGS. 2, 5 and 6 of U.S. Patent number 6,470,975

B1. It is also contemplated that a mechanical plug seal can be used.

The outlets (39, 40) in the marine diverter housing 80 allow the flow of the perforated fluid to return when the pistons P are raised as shown in FIG. 5. An elastomeric layer or coating 35, as described in detail above, can be extended or placed radially on the outer surface of the cylindrical insert 88, preferably where it comes in contact with the seal 43. The support piece 90 is connected by threads to the cylindrical insert 88. The inner diameter 101 of the cylindrical insert 88 and / or the support part 90 varies in size depending on the inner diameter of the marine box 80. It is contemplated that the inner diameter can be between eleven inches and thirty-six inches (27.9 to 91.4 cm), with twenty-five inches (63.5 cm) of typical internal diameter.

However, other diameters and sizes are contemplated, as well as different configurations are mentioned here.

FIG. 5A shows a UMDC box 24B of this invention, which has an upper section 104 and a lower section 106. The upper box section 104 includes circumferential flange 116, which can be positioned over marine diverter 118 and, if desired, sealed with a radial seal. The bottom section of the

20/30 housing 106 includes a cylindrical insert 108 and support piece 110. The upper housing section 104 is threaded with the lower housing 106 on the threaded connection 114, which allows a lower housing 106 sized for the desired marine housing 118 and the top section 104 sized for the desired RCD

100 to be connected. The support part or the turning ring 110 is threaded with the cylindrical insert 108 at the threaded joint 112. The threaded connection 112 allows support pieces with different outside diameters 110 to be positioned in the same cylindrical insert 108 and allows the layer 35 slide over insert 108. It is contemplated that the threaded connection 112 may use reverse threads (left side) that, preferably, tighten in the direction of rotation of the drill rig tubes. It is also contemplated that the threaded connection 114 may use conventional threads on the right side. It is also contemplated that there may be no threaded connections (112, 114), so that the upper part 104 is integral with the lower section 106.

One or more anti-rotation pins 124 can be placed through aligned openings in the threaded connection 114 after the upper section 104 and the lower section 106 are threaded to ensure that connection 114 does not loosen, such as, discussed above, when the drill rig is suspended above the bottom.

Staying with FIG. 5A, the RCD 100 can be secured with a clamp 130 to the upper section 104. Clamp 130 can be manual, hydraulic, pneumatic, mechanical, or other form of remotely operated clamping means. The RCD 100 preferably has a rubber seal 102 bottom seal. It is contemplated that the bottom seal 102 can have a 7/8 inch (2.2 cm) interference fit around the entire tubular probe drilling, to seal

21/30 initially with a pressure of 2000 psi. However, other sizes, interference adjustments and pressures are also contemplated. Seal 102 seals the AB ring between the drill pipe tubing (not shown) and the UMDC housing (24A, 24B, 24C, 24D). It should be understood that different types of RCDs (7, 10, 100) can be positioned in the UMDC 24B box, including RCDs (7, 10, 100) with double rubber separating seals, with both passive and active seals. The UMDC 24B housing can be positioned with marine housing 118, with an active annular elastomer seal 120 actuated by assembly 122, as proposed in U.S. Publication No. 2006/0144622 A1 and shown in FIG. 2A of publication 622. It is contemplated that the assembly 122 can be hydraulic, pneumatic, mechanical, manual or other form of remotely operated means. Upon activation, the annular seal 120 compresses the cylindrical insert 108 and seals the annular space A between the cylindrical insert 108 and the marine diverter housing 118. Although an elastomer annular plug seal 120 is shown, other conventional active seal configurations and liabilities are contemplated, as discussed here. If an elastomer seal, such as seal 43 in FIG. 4 is used, the UMDC 24B box can be configured as shown in FIGS. 2, 5 and 6 of U.S. Patent No. 6,470,975 B1. It is also contemplated that a mechanical plug seal can be used.

The outlets (126, 128) in the marine diverter housing 118 allow the flow of the perforated fluid to return. It is contemplated that the internal diameters of the outlets (126, 128) can be 16 to 20 inches (40.6 to 50.8 cm). However, other opening sizes are also contemplated. It is contemplated that an outlet, such as outlet 128, may lead to a remotely operated valve and a discharge line, which may go to sea and / or into the sea. The other way out, like the

22/30 outlet 126 can lead to the other valve and line, which can go to the probe gas wells and / or mud wells. However, other valves and lines are also contemplated. The drill or operator can decide which valve to open when it closes seal 120 over a tubular inserted in the drill string.

It is contemplated that there may be protections to prevent both valves from being closed at the same time. It is also contemplated that the most frequent would be the line to the gas well that would be opened when the seal 120 is closed, more commonly to circulate more or to safely divert the gas that disassociated from the mud and cuts in the pipe system . It is also contemplated that the operations described above can be used with any incorporation of the UMDC box (24, 24A, 24B, 24C, 24D). The UMDC box inserted (24, 24A, 24B, 24C, 24D) with the RCD (7, 10, 100) allows continuous drilling while circulating the gas outward without constituting a well control problem . In potentially more serious well control scenarios and / or where the gas well may not be able to handle flow rate or pressures, returns may also be directed to the diverter discharge line.

FIG. 6 shows a UMDC box 24C of this invention, which has an upper section 26 and a lower section 50. The upper section 50 includes a circumferential flange 58 and a cylindrical insert 52. The upper box section 26 is threaded with the lower section 50 on the screw connection 30, which allows the lower section 50 to be dimensioned for the desired marine box 60 and the upper section to be dimensioned for the desired RCD 100. FIG. 6 shows a conventional elastomer annular plug seal 43 and a conventional inflatable annular elastomer seal 42 in different compression stages on the right and left sides of the vertical axis. On the right side of the vertical axis, the UMDC box

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24C is positioned with a conventional inflatable seal 42 that has been inflated to the desired pressure. The elastomer plug seal 43 is coupled directly to the inflatable seal 42, despite the annular pistons P being in the lowered position.

On the left side of the vertical axis, the elastomer plug seal 43 further compressed the annular inflatable elastomer seal 42, as the annular pistons P are raised further. The inflatable annular seal of elastomer 42 inflated to a predetermined pressure. The elastomer plug seal 43 and the inflatable seal 42 seal the annular space A between the cylindrical insert 52 and the marine diverter housing 60. As can now be understood, either the inflatable annular seal of elastomer 42 or the annular plug seal of elastomer 43, or a combination of the two, could position the UMDC box 24C and seal the annular space A, as shown in the embodiment of FIG .

6. Inflatable seal 42 could be pressurized to a predetermined pressure in combination with other active and passive seals. The inflatable ring seal of elastomer 42 is preferably pressurized hydraulically or pneumatically remotely through valve port 56. The use of the ring inflatable ring of elastomer 42 and the annular plug seal of elastomer 43 in combination is contemplated, as shown in FIG. 6 can be optimized for maximum efficiency. It is also contemplated that the inflatable ring seal 42 can be reinforced with steel, plastic or other rigid material.

With reference to FIG. 7, another UMDC 24D box with top section 26 and bottom section 66 is positioned with a marine box 70 with a single conventional inflatable annular seal of elastomer 64. The bottom section of box 66 includes circumferential flange 76 and cylindrical insert 72. The inflatable seal 64 is inflated to a predetermined pressure to seal the annular space A between the

24/30 cylindrical insert 72 and the marine diverter box 70. Although a single inflatable annular seal 64 is shown, a plurality of active seals is also contemplated. Inflatable seal 64 can be pressurized hydraulically or pneumatically by remote means via an active valve port 68. A sensor 68A can also be used to remotely monitor the pressure in seal 64. It is contemplated that sensor 68A could be electrical, mechanical or hydraulic. It is contemplated that any inflatable annular seal of elastomer (42, 64) would return to its uninflated form after releasing the pressure.

It is contemplated that the external surface of the cylindrical metal insert (34, 52, 72, 88, 108), specifically where it comes in contact with the annular seal (42, 43, 64, 120), can be profiled, shaped or formed to increase the seal and the tightness between them. For example, the outer surface of the cylindrical metal insert (34, 52, 72, 88, 108) may be uneven, such as rough, serrated, or grooved. In addition, the outer surface of the cylindrical insert (34, 52, 72, 88, 108) can be shaped to match the surface of the annular seal (42, 43, 64, 120) on which it would be contacting. It is also contemplated that a layer of elastomer 35 or a different material could also be profiled, formed or molded to correspond to the outer surface of the cylindrical insert of the metal (34, 52, 72, 88, 108) or annular seal (42, 43, 64, 120), or both, to increase sealing and tightness. In addition, it is contemplated that the surface of the annular seal (42, 43, 64, 120) can be uneven, such as rough, serrated or grooved to increase the seal and tightness.

Going now to Figs. 8-10, different embodiments of a cylindrical insert, generally indicated as I, which include cylindrical inserts 34, 52, 72, 88, and 108; and the annular seal E, which includes annular seals 42, 43, 64, and 120,

25/30 that are illustrated. It should be understood that the outer surface of the cylindrical insert I can be profiled to increase the seal and tightness, depending on the configuration of the annular seal E. For example, FIG. 8 shows the surface of the cylindrical metal insert I which has been grooved to increase the seal and the tightening with seal Ε. FIG. 9 shows another embodiment where the surface of the cylindrical metal insert I was not profiled, but the layer 35A was profiled with grooves to increase the seal and the tightness with the seal Ε. FIG. 10 shows yet another embodiment in which the cylindrical metal insert I was profiled with grooves, so that a consistent layer 35B has a grooved profile. It should be understood that the profiling of the surfaces of the cylindrical insert I and the layer (35, 35A, 35B) and can be manufactured with any combination. It is contemplated that the layer (35, 35A, 35B) can be sandy or rough to further increase its clamping capacity.

It should be understood that the UMDC box (24, 24A, 24B, 24C, 24D) of this invention can be received in a plurality of different marine boxes (38, 60, 70, 80, 118). It should be understood that although a UMDC box (24, 24A, 24B, 24C, 24D) is shown in each of the FIGS. 4-7, the upper sections (3, 26, 104) and the lower sections (2, 28, 50, 66, 106) of the UMDC boxes (24, 24A, 24B, 24C, 24D) are interchangeable, provided the assembled box includes the connection means for connecting an RCD (7, 10, 100), a circumferential flange (1, 32, 58, 76, 116), a cylindrical insert (34, 52, 72, 88, 108), and a support piece (37, 90, 110). It should also be understood that the UMDC box (24, 24A, 24B, 24C, 24D) of the current invention can accommodate different types and sizes of RCDs (7, 10, 100), including those with a single rubber seal, and seals double rubber with both active and / or passive seals. You should also

26/30 understand that although an RCD (10, 100) is shown attached to the UMDC box (24, 24B, 24C, 24D) of the current invention in FIGS. 4, 5A, 6, and 7, and an RCD 7 is shown attached to the UMDC box 24A of this invention in FIG. 5, other oilfield equipment is contemplated to be stuck and / or locked there, such as a non-rotating separator, a non-rotating housing separator, a drilling nozzle, a cable lubricant or an adapter. Also, other fixation methods as known to the art are also contemplated.

An operating tool can be used to install and remove the UMDC box (24, 24A, 24B, 24C, 24D) and the attached RCD (7, 10, 100) in and out of the marine box (38, 60 , 70, 80, 118) through the center of the FC well, as shown in FIG. 1, and / or C, as shown in FIG. 2. A radial locking device, such as a C-ring, a retainer or a series of eyes or clamps on the bottom of the tool, combined with a radial gasket from the RCD (7, 10, 100).

As can now be understood, a UMDC box (24, 24A, 24B, 24C,

24D) of the current invention with an attached RCD (7, 10, 100) can be used to convert any type, size and / or shape of the marine diverter (FD, D, 38, 60, 70, 80, 118) into a diverter rotary to enable a closed and pressurized mud return system, which results in a healthier, safer and environmental performance. Nothing from the marine diverter (FD, D, 38, 60, 70, 80, 118) needs to be removed, including the top of the marine diverter. The UMDC box (24, 24A, 24B, 24C, 24D) with a stuck RCD (7, 10, 100) allows many drilling operations to be conducted with a closed system, without damaging the closed annular seal (42, 43 , 64, 120). The UMDC box (24, 24A, 24B, 24C, 24D) and the

Stuck RCD (7, 10, 100) can be installed relatively quickly without

27/30 modification to the marine diverter and will enable a closed and pressurized mud return system. The outer diameter of the circumferential flange (1, 32, 58, 76, 116) of the UMDC housing (24, 24A, 24B, 24C, 24D) is preferably smaller than the typical internal diameter of 49¹/> inches (1, .26m) of a rotating table of marine piping. As the cylindrical insert (34, 52, 72, 88, 108) expands along the length of the seals (42, 43, 64, 120), a tubular 12 can be lowered and rotated without damaging the sealing elements of the marine diverter, such as as the seals (42, 43, 64, 120), thus saving time, money and increasing operational safety.

The designs of the RCD bearing set (7, 10, 100) can accommodate a wide range of tubular sizes. It is contemplated that the pressure rating of the RCD (7, 10, 100) together with the UMDC box (24, 24A, 24B, 24C, 24D) may be equal to or greater than that of the marine diverter (FD, D, 38, 60, 70, 80, 118). However, other pressure classifications are also contemplated. The UMDC box (24, 24A, 24B, 24C, 24D) with the RCD (7, 10, 100) can be lowered into an open marine diverter (FD, D, 38, 60, 70, 80, 118) without removing the seal (42, 43, 64, 120). Installation saves time, improves safety and preserves environmental integrity. The UMDC box (24, 24A, 24B, 24C, 24D) of this invention can be used, among other applications, (1) in pressure-controlled drilling at sea or in unbalanced drilling operations from a fixed platform or a self-elevating platform, (2) drilling operations with shallow gas risks, (3) drilling operations in which it is beneficial to conduct a pipe or other tubular movement with a closed diverter system, and (4) drilling operations with simultaneous circulation of the perforated gas.

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Method of Use

A conventional annular marine diverter BOP (FD, D, 38, 60, 70, 80, 118), including, but not limited to diverters (FD, D) as configured in FIGS. 1 and 2, which can be converted into a rotating marine diverter, as shown in FIGS. 4-7, using the UMDC box (24, 24A, 24B, 24C, 24D) of this invention. The upper part of the conventional annular box of the BOP (38, 60, 70, 80, 118) does not need to be removed with the method of this invention, although this is possible if desired. The conventional annular seal (42, 43, 120) can be left in place as in FIGS. 4, 5, 5A, and 6. In the drill pipe, the upper part (3, 26, 104) of the UMDC box (24, 24A, 24B, 24C, 24D) is wired to the desired upper part (2, 28, 50, 66, 106) suitable for the conventional marine diverter box (38, 60, 70, 80, 118) as long as the assembled box includes connection means for connecting an RCD (7, 10, 100), a circumferential flange (1, 32, 58, 76, 116), a cylindrical insert (34, 52, 72, 88, 108), and a support piece (37, 90, 110). The outer surface of the cylindrical insert (34, 52, 72, 88, 108) of the lower section of the box (2, 28, 50, 66, 106) may have an elastomer layer (35, 35A, 35B). The insert (34, 52, 72, 88, 108) and / or the layer (35, 35A, 35B) can be profiled as desired to increase the seal and tightness.

The drill pipe, RCD (7, 10, 100) can be tightened with the clamp (16, 130) or locked with the locking set 6 to the desired UMDC box (24, 24A, 24B, 24C, 24D). The RCD (7, 10, 100) and UMDC (24, 24A, 24B, 24C, 24D) can be lowered through the center of the well (FC, C) with a hydraulic operating tool or with a tool joint as previously described and positioned with the conventional BOP annular box (38, 60,

70, 80, 118). When the flange (1, 32, 58, 76, 116) of the UMDC housing (24, 24A, 24B,

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24C, 24D) couples the top part of the conventional annular BOP box (38, 60, 70, 80, 118), the operational tool is disengaged from the RCD box (7, 10, 100) / UMDC (24, 24A, 24B, 24C, 24D). If an inflatable seal (42, 64) is used, it is inflated to a predetermined pressure to hold the UMDC box (24, 24A,

24B, 24C, 24D) with the conventional annular BOP box (38, 60, 70, 80, 118). If the elastomer annular plug seal 43 is left in place and can be moved up and in with the annular pistons P to secure the UMDC housing (24, 24A, 24B, 24C, 24D). As previously described in FIG. 6, when combined annular elastomer plug seal 43 and the unreliable seal (42, 64) are used, the inflatable seal (42, 64) can be inflated with a predetermined pressure in different combinations to move the annular pistons P up and down move the annular plug seal 43 upwards and inwards to retain the UMDC box (24, 24A, 24B, 24C, 24D). The desired annular seal (42, 43, 64, 102) seals ring A between the UMDC box (24, 24A, 24B, 24C and 24D) and the marine box (38, 60, 70, 80, 118).

After the UMDC box (24, 24A, 24B, 24C and 24D) is fixed, drilling can begin. The tubular 12 can be placed through the center of the well (FC, C) and then through the RCD (7, 10, 100) for drilling or other operations. The top seal of RCD 10 and / or the bottom rubber seal (14,

102) must rotate with the tubular and allow the tubular to slide and seal the AB ring between the tubular and UMDC box (24, 24A, 24B, 24C, 24D) so that the perforated fluid returns (shown with arrows in FIG 4) be driven through the exits (39, 40, 126, 128). The perforated liquid returns can be deflected, as described above by closing the annular seals (42, 43, 64, 120).

When drilling stops, the RCD (7, 10, 100) can be manually or manually

30/30 remotely loose and / or unlocked and lift a sufficient distance out of the UMDC box (24, 24A, 24B, 24C, 24D) so that the rubber seal (14, 102) can be checked for worn or replaced.

In a brief summary, according to the embodiments of the invention, a converter box of the universal marine diverter (UMDC) is attached or locked to a rotary control device. The UMDC box assembled with the RCD is introduced in a marine diverter above the water surface to allow conversion between the conventional open and non-pressurized mud return drilling system and a closed and pressurized mud return system used in drilling with controlled pressure and low balance.

Although the invention describes preferred embodiments, as set out above, it is to be understood that such embodiments are illustrative only and that the claims are not limited and these embodiments. Those with technical knowledge will be able to make changes and alternatives due to the disclosure, contemplated as within the scope of the attached claims. Each feature disclosed or illustrated in the current specification can be incorporated into the invention, either alone or in an appropriate combination with any other feature disclosed or illustrated here.

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