Lockable flange for underwater drilling assembly

Abstract

The invention discloses an underwater drilling assembly and system. Underwater drilling assemblies and systems include a drilling assembly, a frame for the drilling assembly, and a connecting flange assembly to be secured to a hull. The subsea drilling assembly and system also includes a waste box and an automatic vent valve assembly.

Description

[0001] Cross - Reference to Related Applications

[0002] This application claims priority to U.S. Provisional Patent Application Serial No. 63 / 426,591, filed on November 18, 2022, titled "MARINE SALVAGE DRILL ASSEMBLIES AND SYSTEMS", under 35 U.S.C. § 119(e), the entire disclosure of which is incorporated herein by reference. Background of the Invention

[0003] The present disclosure relates to drilling systems, assemblies, and components that can be used for marine salvage. Summary of the Invention

[0004] In various aspects of the present disclosure, an underwater drilling system for marine salvage is disclosed. The underwater drilling system includes a frame, a drilling assembly supported by the frame, and a connection flange assembly configured to be attached to a hull by the drilling assembly. For example, hydrocarbons can be extracted from the hull through the connection flange assembly after the connection flange assembly is attached to the hull and the drilling assembly is disengaged from the connection flange assembly. Brief Description of the Drawings

[0005] The various aspects described herein and their advantages can be understood from the following description in conjunction with the accompanying drawings.

[0006] Figure 1 is a perspective view of an underwater drilling system according to at least one aspect of the present disclosure, the underwater drilling system including a frame, a drilling assembly supported by the frame, and a connection flange assembly configured to be secured to a hull by the underwater drilling system.

[0007] Figure 2 is according to at least one aspect of the present disclosure Figure 1 partial perspective view of the underwater drilling system.

[0008] Figure 3 is according to at least one aspect of the present disclosure Figure 1 partial perspective view of the underwater drilling system.

[0009] Figure 3A is according to at least one aspect of the present disclosure Figure 1 partial perspective view of the underwater drilling system.

[0010] Figure 4 is according to at least one aspect of the present disclosure Figure 1 top view of the underwater drilling system.

[0011] Figure 5 is according to at least one aspect of the present disclosure Figure 1Front view of the underwater drilling system.

[0012] Figure 6 is of an underwater drilling system according to at least one aspect of the present disclosure Figure 1 Side view of the underwater drilling system.

[0013] Figure 7 is of an underwater drilling system according to at least one aspect of the present disclosure Figure 1 Perspective view of an attachment leg of the underwater drilling system, wherein the attachment leg includes a fluid actuator, an extendable leg assembly attached to the fluid actuator, and a suction cup base configured to be fixed to the hull.

[0014] Figure 8 is of an attachment leg according to at least one aspect of the present disclosure Figure 7 Partial perspective view of the attachment leg.

[0015] Figure 9 is of an attachment leg according to at least one aspect of the present disclosure Figure 7 Cross-sectional view of a portion of the attachment leg, wherein the extendable leg assembly includes an upper leg portion attached to and movable by the fluid actuator and a lower leg portion spring-loaded against the upper leg portion.

[0016] Figure 10 is of an attachment leg according to at least one aspect of the present disclosure Figure 1 Schematic view of the underwater drilling system and its attachment leg configured to engage a concave hull surface, wherein the attachment leg is shown in a retracted configuration.

[0017] Figure 11 is of an attachment leg according to at least one aspect of the present disclosure Figure 10 Schematic view of the underwater drilling system and the attachment leg, wherein the attachment leg is shown in an extended configuration.

[0018] Figure 12 is of an attachment leg according to at least one aspect of the present disclosure Figure 10 Schematic view of the underwater drilling system and the attachment leg, wherein the attachment leg is shown in a first holding configuration.

[0019] Figure 13 is of an attachment leg according to at least one aspect of the present disclosure Figure 10 Schematic view of the underwater drilling system and the attachment leg, wherein the attachment leg is shown in a second holding configuration.

[0020] Figure 14 is of an attachment leg according to at least one aspect of the present disclosure Figure 1 Schematic view of the underwater drilling system and its attachment leg configured to engage a convex hull surface, wherein the attachment leg is shown in a retracted configuration.

[0021] Figure 15 is of an attachment leg according to at least one aspect of the present disclosure Figure 14Schematic diagram of an underwater drilling system and an attachment leg, where the attachment leg is shown in an extended configuration.

[0022] Figure 16 is according to at least one aspect of the present disclosure Figure 14 Schematic diagram of an underwater drilling system and an attachment leg, where the attachment leg is shown in a first retention configuration.

[0023] Figure 17 is according to at least one aspect of the present disclosure Figure 14 Schematic diagram of an underwater drilling system and an attachment leg, where the attachment leg is shown in a second retention configuration.

[0024] Figure 18 is according to at least one aspect of the present disclosure Figure 1 Partial cross-sectional view of a self-tapping connection stud among a plurality of self-tapping connection studs of an underwater drilling system, where the self-tapping connection stud is configured to be drilled into the hull to Figure 1 fix the connection flange assembly of the underwater drilling system to the hull, and where the self-tapping connection stud includes a cutting body, self-tapping threads, a shank, and a driveable head.

[0025] Figure 19 is according to at least one aspect of the present disclosure Figure 18 of the self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in an initial unactuated position, and where the receiving structure includes a sealing ring and a receiving cavity, and the self-tapping connection stud is configured to pass through the receiving cavity.

[0026] Figure 20 is according to at least one aspect of the present disclosure Figure 18 of the self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in an initial contact position.

[0027] Figure 21 is according to at least one aspect of the present disclosure Figure 18 of the self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in a first partial drilling position.

[0028] Figure 22 is according to at least one aspect of the present disclosure Figure 18 of the self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in a second partial drilling position.

[0029] Figure 23 is according to at least one aspect of the present disclosureFigure 18 Self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in the fully drilled position.

[0030] Figure 24 is according to at least one aspect of the present disclosure Figure 18 Self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in the fully installed position.

[0031] Figure 25 is according to at least one aspect of the present disclosure Figure 18 Self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in the first failure configuration.

[0032] Figure 26 is according to at least one aspect of the present disclosure Figure 18 Self-tapping connection stud and Figure 1 Partial cross-sectional view of the receiving structure of the connection flange assembly, where the self-tapping connection stud is shown in the second failure configuration.

[0033] Figure 27 is according to at least one aspect of the present disclosure Figure 1 Partial perspective view of an underwater drilling system, where the underwater drilling system further includes a locking assembly configured to couple the connection flange assembly to the frame and decouple it from the frame.

[0034] Figure 28 is according to at least one aspect of the present disclosure Figure 1 Partial perspective view of an underwater drilling system, where the frame includes a lower platform and a male coupling portion attached to the lower platform, where the male coupling portion is configured to be received by the female coupling portion of the connection flange assembly, and where the locking assembly includes a locking ring configured to rotate to lock and unlock the male coupling portion and the female coupling portion.

[0035] Figure 29 is according to at least one aspect of the present disclosure Figure 1 Perspective view of the connection flange assembly of an underwater drilling system, where the connection flange assembly includes a knife gate configured to provide an actuatable seal between a lower drill cavity and an upper drill cavity defined within the connection flange assembly.

[0036] Figure 30 is according to at least one aspect of the present disclosure Figure 1 Cross-sectional view of the connection flange assembly, the lower platform of the frame, and the locking assembly of an underwater drilling system.

[0037] Figure 31of a drill string, a male coupling portion of a frame, a connection flange assembly, and a waste box of an underwater drilling system fluidly coupled to a drill cavity within the male coupling portion, according to at least one aspect of the present disclosure, where the waste box is configured to collect waste liquid, and where the drill string is shown in an initial position. Figure 1 Schematic illustration

[0038] Figure 32 of a drill string, a male coupling portion, a connection flange assembly, and a waste box, according to at least one aspect of the present disclosure, where the drill string is shown in a chamber pressurization position. Figure 31 Schematic illustration

[0039] Figure 33 of a drill string, a male coupling portion, a connection flange assembly, and a waste box, according to at least one aspect of the present disclosure, where the drill string is shown in a hole cutting position, where fluid passes through the hull and into the drill cavity. Figure 31 Schematic illustration

[0040] Figure 34 of a drill string, a male coupling portion, a connection flange assembly, and a waste box, according to at least one aspect of the present disclosure, where the drill string is shown in a retracted position and the knife gate of the connection flange assembly is shown in an actuated configuration to provide a seal between an upper drill cavity portion of the male coupling portion and a lower drill cavity portion of the connection flange assembly. Figure 31 Schematic illustration

[0041] Figure 35 of a drill string, a male coupling portion, a connection flange assembly, and a waste box, according to at least one aspect of the present disclosure, where the drill string is shown in a retracted position and the knife gate of the connection flange assembly is shown in an actuated configuration, where a pump is configured to drain waste liquid within the drill cavity into the waste box. Figure 31 Schematic illustration

[0042] Figure 36 of a drill string, a male coupling portion, and a waste box separated from a Figure 31 connection flange assembly of Figure 31 , where the waste box is filled with waste liquid.

[0043] Figure 37 of a partial perspective view of an underwater drilling system, according to at least one aspect of the present disclosure, where the underwater drilling system includes an automatic exhaust valve assembly configured to automatically vent air within the drill cavity, and where the automatic exhaust valve assembly includes a fluid pivot coupling, a float, and an inner automatic exhaust valve. Figure 1 Schematic illustration

[0044] Figure 38 of a cross-sectional view of an automatic exhaust valve assembly, according to at least one aspect of the present disclosure. Figure 37 Schematic illustration

[0045] Figure 39 FIG. is a schematic view of a system including a drilling assembly and various components for operating the drilling assembly according to at least one aspect of the present disclosure.

[0046] Throughout the various views, corresponding reference numerals represent corresponding components. The examples set forth herein illustrate one form of various aspects of the present disclosure, and these examples should not be construed as limiting the scope of the invention in any way. DETAILED DESCRIPTION

[0047] The applicant of the present application owns the following patent applications, all of which were filed on November 17, 2023, and each patent application is hereby incorporated by reference in its entirety:

[0048] 1. PCT patent application titled "Frame for Underwater Drilling Assembly"; Attorney Docket No. 220323-1PCT;

[0049] 2. PCT patent application titled "Fasteners for Underwater Drilling Assembly"; Attorney Docket No. 220323-2PCT;

[0050] 3. PCT patent application titled "Scrap Box for Underwater Drilling Assembly"; Attorney Docket No. 220323-4PCT; and

[0051] 4. PCT patent application titled "Exhaust Assembly for Underwater Drilling Assembly"; Attorney Docket No. 220323-5PCT.

[0052] Before explaining the various aspects of the drilling assembly and system, it should be noted that the application or use of the illustrated examples is not limited to the details of the construction and component arrangements shown in the drawings and description. The illustrated examples can be implemented or combined in other aspects, variations, and modifications, and can be practiced or carried out in various ways. Additionally, unless otherwise stated, the terms and expressions used herein are chosen for the convenience of the reader in describing the illustrated examples and are not intended to limit their purpose. Similarly, it will be understood that one or more of the aspects, expressions of aspects, and / or examples described below can be combined with one or more of the other aspects, expressions of aspects, and / or examples described below.

[0053] One of the functions of marine salvage can include removing or extracting fluids contained within a disabled vessel or marine vehicle. Leaving fluids within a disabled vessel can pose a potential environmental hazard. A vessel can be classified as disabled if it sinks to the bottom of the sea or otherwise becomes unable to return to a state where the vessel can independently discard its fluids. Fluids to be extracted can include, for example, fuel. In one instance, the fuel is contained within a fuel tank of the vessel. In another instance, the fuel is contained within the cargo area of the vessel. In any case, extracting fluids from a disabled vessel can mitigate the risk of potential environmental hazards.

[0054] In one instance, a method of extracting fluids from a disabled vessel involves a human diver manually drilling a hole in the vessel. Manual drilling requires many steps and equipment. The diver must locate the fluid to be extracted and evaluate where to drill in the vessel to extract the fluid. In many cases, the framework of the vessel is located behind or beside the hull or outer skin of the vessel. This poses a risk of drilling into the framework, which can cause the drill bit to fail and / or fluid to leak from the vessel. Current methods of deciding where to drill involve tapping on the hull of the vessel and listening for the tone of the tap until a hollow tone tap is found - similar to locating a joist in a wall.

[0055] In one instance, once the diver has located the position to drill, the diver attaches a flange member to the hull. The flange member can be attached to the hull of the vessel, for example, by inserting self - tapping threaded bolts and using the threaded bolts to secure the flange to the hull. Once the flange is attached to the hull of the vessel, a valve is attached to the flange, for example, by bolts. Once the valve is installed, the diver installs a drilling assembly by bolting the drilling assembly to the valve. Once the drilling assembly is installed, the valve is opened. Now the diver can activate the drill, and thus, the drill bit is configured to drill through the valve and flange into the hull of the vessel. The drill bit can serve as a temporary fluid stopper to prevent fluid from spilling during the drilling process. Once the hole is drilled, the drill bit is lifted above the valve, the valve is closed, and the drill is removed. Once the drill is removed, the fluid can be extracted through a port in the valve.

[0056] In at least one instance, various marine salvage tasks are performed by an underwater drilling system capable of performing several steps of marine salvage with minimal diver intervention or no diver intervention at the drilling site. An overview of the underwater drilling system will now be described. Several components discussed below are described in more detail throughout this disclosure. First, a vessel containing all the necessary equipment to extract fluid from a sunken ship is positioned near the sunken ship. Once the vessel is in place, the underwater drilling system is placed on the water surface using a crane set on the vessel, where the assembly floats through a plurality of removable floats. Then, a remotely operated vehicle (ROV) is deployed to connect to the underwater drilling system. After the ROV is connected to the underwater drilling system, the floats are removed to allow the ROV to lower the underwater drilling system to the drilling site. The underwater drilling system is moored to a control interface on the vessel to transfer hydraulic fluid between a hydraulic power pack and the underwater drilling system and to transfer electrical and data signals between the control interface and the underwater drilling system.

[0057] Once the underwater drilling system is positioned at the drilling location, the underwater drilling system is positioned against the surface of the sunken ship by the ROV. In at least one instance, the ROV pushes the underwater drilling system against the surface of the sunken ship with a predetermined holding force. At this time, the attachment legs are actuated through the control interface on the vessel to attach the underwater drilling system to the surface of the sunken ship and hold it on the surface of the sunken ship. Once the attachment legs engage the surface of the sunken ship, the ROV can reduce or stop applying the predetermined holding force and allow the underwater drilling system to be held against the surface of the sunken ship by the attachment legs.

[0058] After the engagement of the attachment legs, the drilling assembly of the underwater drilling system is used to fix a flange connection assembly to the surface of the sunken ship with a plurality of self-tapping connection studs and to drill a main hole in the surface of the sunken ship for fluid extraction. The drilling assembly includes two linear fluid actuators and a rotary fluid actuator. Each linear fluid actuator is configured to linearly actuatedrill rods, and each drill rod is configured to be rotated by the rotary fluid actuator through a transmission assembly. One of the drill rods is configured to drive self-tapping connection studs into the surface of the sunken ship to fix the flange connection assembly to the surface of the sunken ship, and the other drill rod is configured to drill a main hole in the surface of the sunken ship for fluid extraction.

[0059] The flange connection assembly is fixed to the hull by a plurality of self-tapping connection studs. The flange connection assembly includes a plurality of receiving structures configured to receive waste fluid that may leak due to driving the self-tapping connection studs into the hull. In at least one case, one or more of the self-tapping connection studs may break, and in such a case, the receiving structures are configured to prevent waste fluid from leaking from the flange connection assembly due to the break.

[0060] After the flange connection assembly is secured and the primary hole is drilled, the knife gate of the flange connection assembly is actuated to seal the flange connection assembly to prevent additional fluid from escaping from the primary hole of the sunken vessel beyond the fluid that escaped during drilling of the primary hole. The knife gate divides the drill cavity (through which the drill pipe passes to drill the primary hole) into an upper drill cavity and a lower drill cavity. At this time, the fluid and / or debris that escaped from the primary hole during drilling of the primary hole is trapped in the upper drill cavity defined in the male coupling portion of the frame of the underwater drilling system. As discussed in more detail below, the male coupling portion is secured to the flange connection assembly by a locking mechanism.

[0061] Now the fluid trapped in the upper drill cavity is drained from the upper drill cavity into the waste box of the underwater drilling system in an attempt to reduce or eliminate the escape of waste fluid into the surrounding medium (e.g., seawater) when the frame of the underwater drilling assembly and the drilling assembly are separated from the installed connection flange assembly. The waste box is mounted to the frame and is fluidly coupled to the upper drill cavity through the male coupling portion. A pump is provided to pump seawater into the upper drill cavity to drain the waste fluid into the waste box.

[0062] The underwater drilling system further includes an automatic vent assembly that is fluidly coupled to the upper drill cavity to automatically release any trapped air encountered within the sunken vessel. The automatic vent assembly is pivotally coupled to the frame to allow the automatic vent assembly to pivot to its highest position to facilitate the discharge of the trapped air from the automatic vent assembly.

[0063] After the waste fluid is drained from the upper drill cavity, the locking mechanism is actuated to unlock the male and female coupling portions, thereby allowing the drilling assembly, the frame, and various other components of the underwater drilling system to be removed from the installed connection flange assembly. In addition to unlocking the male and female coupling portions of the flange connection assembly, the attachment legs are also released from the surface of the sunken vessel to allow the frame, the drilling assembly, and various other components of the underwater drilling system to be completely separated from the installed connection flange assembly.

[0064] Once removed from the installed flange connection assembly, the underwater drilling system can be transported back to the surface by, for example, an ROV to reinstall the floats, reload additional flange connection assemblies, clean and / or flush the waste box, and prepare for the next installation of the flange connection assembly. In at least one case, the floats are reinstalled onto the frame before the above steps occur. In at least one case, another flange connection assembly is aligned with the male coupling portion of the frame, and the locking mechanism locks the male coupling portion and the new flange connection assembly. The underwater drilling system can then be lowered back to the new drilling site for the installation of the new flange connection assembly.

[0065] After installation of the flange connection assembly, the ROV can be configured to connect a hose assembly to the flange connection assembly, release a knife gate seal, and extract fluid from a sunken ship, for example, by vacuum. In at least one case, after fluid extraction, the flange connection assembly is resealed.

[0066] All steps described herein can be performed by the ROV alone, by the ROV with the assistance of a diver, and / or by the diver alone.

[0067] Hydraulic hoses and / or electrical transmission lines can be stored on reels on a vessel. For example, hydraulic hoses and / or electrical transmission lines that transmit fluid and / or electrical signals between the vessel and a transfer center can be stored on one or more reels positioned on the vessel.

[0068] Details of various devices, systems, and / or components for marine salvage can be found in U.S. Patent Application Serial No. 16 / 356,398 (now U.S. Patent No. 11,014,639, titled "MARINE SALVAGE DRILL ASSEMBLIES AND SYSTEMS"), which is hereby incorporated by reference in its entirety.

[0069] Figures 1-9 An underwater drilling system 1000 is shown in accordance with one aspect of the present disclosure. The underwater drilling system 1000 includes a frame 1100 configured to support various components of the underwater drilling system 1000, a plurality of attachment legs 1300 attached to the frame 1100 and configured to hold the underwater drilling system 1000 to a hull, and a drilling assembly 1400 configured to drill a primary hole in the hull and secure a flange connection assembly 1600 to the hull with a plurality of self-tapping attachment studs 1200. The underwater drilling system 1000 further includes a waste bin assembly 1800 mounted to the frame 1100 and configured to collect waste fluid, and an automatic exhaust valve assembly 1900 configured to automatically expel air encountered through the hull.

[0070] The underwater drilling system 1000 also includes various other components, such as a hot-swap connector assembly 1010 configured to provide a global connection point for fluid and / or electrical line connections. In at least one case, the ROV is configured to be directly connected to the hot-swap connector assembly 1010, and the ROV is connected to an electrical and / or hydraulic supply source on the vessel. In at least one case, the ROV is configured to connect a tether from the vessel to the hot-swap connector assembly 1010. In at least one case, the underwater drilling system 1000 also includes one or more cameras, lights, power supplies, and ROV wrist mechanisms, which are attached to the frame 1100. In at least one case, the ROV is configured to be attached to the ROV wrist mechanism to allow the ROV to manipulate the underwater drilling system 1000. In at least one case, the underwater drilling system 1000 also includes a central valve box. In at least one case, one or more hydraulic components of the underwater drilling system 1000 include separate supply and return lines connected to the central valve box, and the central valve box includes main supply and return lines. In at least one case, the main supply and return lines are fed to the vessel through the hot-swap connector assembly.

[0071] The underwater drilling system 1000 also includes a float member 1005 configured to be manually and / or by the ROV attached to and detached from the frame 1100. In at least one case, the float member 1005 is configured to assist in the transfer of the underwater drilling system 1000 from the vessel to the ocean, for example, by allowing the underwater drilling system 1000 to float on the sea surface. At this time, the ROV can be attached to the underwater drilling system 1000. Once the ROV is attached to the underwater drilling system 1000, the float can be manually and / or by the ROV removed, thereby allowing the underwater drilling system 1000 to be taken to the drilling site, for example, by the ROV and / or divers.

[0072] Main reference Figure 2 and Figure 3 With primary reference to Figure 2 and Figure 3holds a plurality of self-tapping connection studs 1200, where the studs 1200 are aligned with corresponding orifices in the flange connection assembly 1600 such that the drilling assembly 1400 can drive the studs 1200 into the flange connection assembly 1600 to secure the flange connection assembly 1600 to the hull. In at least one case, the studs 1200 are held within the lower platform 1120 by, for example, a bushing structure 1121 configured to provide a tight fit for each of the studs 1200 therein to hold the studs 1200 in a pre-arranged configuration prior to being driven by the drilling assembly 1400.

[0073] The central support structure 1101 further includes a top platform 1102. The top platform 1102 includes hooks 1103 configured to be engaged by a crane to pick up and lower the underwater drilling system 1000.

[0074] Main reference Figure 2 , Figure 3 and Figures 7-9 , the attachment legs 1300 are attached to the frame 1100 and are configured to hold the underwater drilling system 1000 to the hull. Each attachment leg 1300 is attached to the lower platform 1120. Each attachment leg 1300 includes a linear fluid actuator 1310, an extensible (or telescoping) leg assembly 1320, and a suction cup base 1370, the leg assembly 1320 being attached to the fluid actuator 1310, the suction cup base 1370 being attached to the extensible leg assembly 1320 via a gimbal 1360. The suction cup base 1370 is configured to provide a holding force against the hull. The extensible leg assembly 1320 is configured to allow the underwater drilling system 1000 to float relative to the hull, which will be discussed in more detail below. The linear fluid actuator 1310 includes an output shaft 1311 configured to move up and down in response to fluid actuation. The extensible leg assembly 1320 includes a housing member 1321 fixedly attached to the linear fluid actuator 1310, an upper leg portion 1330 slidably supported within the housing member 1321, and a lower leg portion 1350 slidably supported within the housing member 1321. The upper leg portion 1330 is attached to the output shaft 1311 and is directly translated up and down by the output shaft 1311. The lower leg portion 1350 is spring-loaded against the upper leg portion 1330 by a spring mechanism 1340.

[0075] The spring mechanism 1340 includes a plunger shaft 1341 slidably supported within an upper leg portion 1330. The plunger shaft 1341 includes a plunger head 1342. The spring mechanism further includes a spring 1343 and a retaining nut 1344 positioned within the upper leg portion 1330. The spring 1343 is positioned between the plunger head 1342 and the nut 1344 such that when the suction cup base 1370 engages the hull (e.g., by hydraulically applying suction), as the upper leg portion 1330 is translated upward by the output shaft 1311, the upper leg portion 1330 expands relative to the lower leg portion 1350 due to the retaining force provided by the suction cup base 1370 and the spring 1343. The lower leg portion 1350 is pinned to the plunger shaft 1341 and a slot 1322 of the housing member 1321 via a pin 1345. The pin 1345 holds the plunger shaft 1341 to the lower leg portion 1350 to permit retraction of the upper leg portion 1330 by the fluid actuator 1310. The upper leg portion 1330 is spring-loaded against the nut 1344. As will be discussed in more detail below, the attachment leg 1300 is configured to allow the underwater drilling system 1000 to float relative to the hull while still providing a retaining force through the suction cup base 1370.

[0076] Each suction cup base 1370 is attached to the lower leg portion 1350 via a gimbal 1360 to allow each attachment leg 1300 to conform to an uneven surface of the hull, as will be discussed in more detail below. The suction cup base 1370 includes a suction chamber 1371 defined in the bottom side of the suction cup base 1370 and a plurality of suction holes 1372 that are fluidly connectable to a fluid line such that a vacuum can be created in the suction chamber 1371 to secure each attachment leg 1300 to the hull.

[0077] Figures 10-13 and Figures 14-17 are schematic views of attaching the underwater drilling system 1000 to a concave hull 2001 and a convex hull 2002 via the attachment legs 1300, respectively. As Figure 10 can be seen, the extendable leg assembly 1320 is shown in a retracted configuration. Starting from the retracted configuration, the fluid actuator 1310 is actuated to advance the output shaft 1311, thereby advancing the extendable leg assembly 1320 and the suction cup base 1370 toward the concave hull 2001 and into Figure 11 the extended position shown. As Figure 11 can be seen, the suction cup base 1370 pivots or rotates to conform to the concave hull 2001 upon contact between the suction cup base 1370 and the concave hull 2001. After the suction cup base 1370 is in sufficient contact with the concave hull 2001, air and / or water is drawn out of the suction chamber 1371 defined in the suction cup base 1370 through the suction holes 1372 to secure the suction cup base 1370 to the concave hull 2001. In at least one instance, a suction pump or vacuum pump 1003 (Figure 2 to achieve suction within the suction chamber 1371.

[0078] In at least one case, sufficient contact between the suction cup base 1370 and the hull 2001 can be automatically determined by a pre-configured pressure relief valve that is configured to stop the extension of the output shaft 1311 when a predetermined pressure is reached. This configuration can prevent the fluid actuator 1310 from lifting the underwater drilling system 1000 off the hull 2001. In at least one case, the ROV is configured to maintain the application of a predetermined amount of positive downward force on the underwater drilling system to hold the underwater drilling system 1000 against the hull 2001. In at least one case, the gasket 1690 allows a degree of self-leveling of the underwater drilling system 1000.

[0079] After the suction force is established in the suction cup base 1370, the output shaft 1311 is retracted by the fluid actuator 1310 to place the attachment leg in a first holding configuration as seen in Figure 12 The output shaft 1311 retracts to pull the upper leg portion 1330 upward relative to the lower leg portion 1350, thereby expanding the expandable leg assembly 1320. This is achieved by the spring mechanism 1340. This holding configuration causes the attachment leg 1300 to pull the underwater drilling system 1000 toward the hull 2001. In at least one case, the output shaft 1311 is locked after this holding configuration is reached. When the flange connection assembly 1600 is installed in the hull 2001 while maintaining the maximum suction holding force, the expandable leg assembly 1320 allows the underwater drilling system to float or move slightly. In other words, due to the spring 1343, the underwater drilling system 1000 is able to index toward the hull 2001 when compressing the gasket 1690. In at least one case, this arrangement can eliminate the hydraulics required to compensate for the movement of the underwater drilling system 1000 relative to the hull 2001 when compressing the gasket 1690. In at least one case, hydraulics (such as the hydraulics of the attachment leg 1300) are used in addition to the spring mechanism 1340 to index the underwater drilling system 1000. In at least one case, the output shaft 1311 is not locked after the first holding configuration is reached.

[0080] Due to the spring mechanism 1340, the underwater drilling system 1000 can float, causing the attachment leg 1300 to obtain a Figure 13The second retention configuration shown. In at least one case, during installation of the flange connection assembly 1600 by the self-tapping connection bolts 1200, the underwater drilling system 1000 is pulled closer to the hull 2001. This vertical proximity is due to the compression of the gasket 1690 of the flange connection assembly 1600 between the outer edge of the flange connection assembly 1600 and the hull 2001 when the threads 1230 of the self-tapping connection bolts 1200 engage into the hull 2001. This engagement pulls the flange connection assembly 1600 towards the hull 2001, thereby compressing the gasket 1690. In the absence of the extensible leg assembly, after the attachment legs of the underwater drilling system apply a holding force to the hull, the vertical movement of the underwater drilling system 1000 relative to the hull may cause instability in the magnitude of the holding force applied by the attachment legs. In at least one case, this vertical approximation results in a loss of suction supplied by the attachment legs utilizing suction cups.

[0081] As described above, Figures 14-17 is a schematic view of attaching the underwater drilling system 1000 to the convex hull 2002 via the attachment legs 1300. The attachment legs 1300 operate in a manner similar to that discussed above with respect to Figures 10-13 In this case, the gimbal 1360 allows the suction cup base 1370 to pivot in a direction different from the direction in which the suction cup base 1370 pivots when contacting the concave hull 2001.

[0082] As described above, the drilling assembly 1400 of the underwater drilling system 1000 is configured to drill a main hole in the hull and fix the flange connection assembly 1600 to the hull with the plurality of self-tapping connection studs 1200. Referring again mainly to Figures 1-3 , the drilling assembly 1400 includes a rotary fluid actuator 1410 operatively coupled to a transmission 1415. The drilling assembly 1400 also includes a first linear fluid actuator 1420 and a second linear fluid actuator 1440. The first linear fluid actuator 1420 is configured to linearly translate the outer drill pipe 1430, and the second linear fluid actuator 1440 is configured to linearly translate the main drill pipe 1450. The outer drill pipe 1430 is configured to be rotated by the rotary fluid actuator 1410 via the transmission 1415 to drive the self-tapping connection bolts 1200. The main drill pipe 1450 is also configured to be rotated by the rotary fluid actuator 1410 via the transmission 1415 to drill a main hole for fluid extraction in the hull. In at least one instance, the transmission 1415 includes a clutch that is configured to selectively and independently drive each drill pipe 1430, 1450. In at least one instance, when the rotary fluid actuator 1410 is actuated, each drill pipe 1430, 1450 rotates simultaneously.

[0083] The drilling assembly 1400 also includes a rotary carriage assembly 1470 surrounding the main drill pipe 1450 (Figure 3A ). The rotary carriage assembly 1470 is configured to rotate the entire drilling assembly 1400 about a drill axis defined by the main drill pipe 1450 so as to align the outer drill pipe 1430 with each self - tapping connection stud 1200. Main reference Figure 3A , the rotary carriage assembly 1470 includes a first linear fluid actuator 1471 attached to the lower platform 1120, a second linear fluid actuator 1472, a drive link 1475 connected to the first linear fluid actuator 1471 and the second linear fluid actuator 1472, and a rotary carriage gear segment 1480 around the main drill pipe 1450. The drive link 1475 is operably engaged with the rotary carriage gear segment 1480. The linear fluid actuators 1471, 1472 can be actuated cooperatively to rotate the rotary carriage gear segment 1480, thereby aligning the outer drive shaft 1430 with each self - tapping connection stud 1200.

[0084] When the outer drive shaft 1430 is aligned with one of the self - tapping connection studs 1200, the first linear fluid actuator 1420 is actuated to advance the outer drive shaft 1430 toward the drive head 1211 of the self - tapping connection stud 1200 in its pre - arranged configuration. Once the outer drive shaft 1430 is operably engaged with the drive head 1211, the linear fluid actuator 1420 and the rotary fluid actuator 1410 can be actuated cooperatively to linearly and rotationally drive the self - tapping connection stud 1200 from its pre - arranged configuration into the hull. Once the self - tapping connection stud 1200 is installed or broken, as discussed in more detail below, the first linear fluid actuator 1420 is actuated to retract the outer drill pipe 1430 to its original position. Once the outer drill pipe 1430 is in its original position, the rotary carriage gear segment 1480 rotates to align the outer drill pipe 1430 with another self - tapping connection stud 1200. This process is repeated until all of the self - tapping connection studs 1200 are fixed to the hull and / or the flange connection assembly 1600 is sufficiently installed in the hull. In at least one instance, one or more of the self - tapping connection studs 1200 may break during the attachment of the flange connection assembly 1600. In at least one instance, it is not necessary to drive each self - tapping connection stud 1200 completely into the hull to achieve sufficient attachment of the flange connection assembly 1600 to the hull.

[0085] As described above, the flange connection assembly 1600 is fixed to the hull by the self - tapping connection studs 1200. In various cases, debris and / or waste liquid may be forced out of the holes drilled and / or tapped by each self - tapping connection stud 1200. Accordingly, the flange connection assembly 1600 includes a receiving structure 1650 for each self - tapping connection stud 1200 to attempt to address the issue of escaping debris and / or waste liquid. The receiving structure 1650 and the self - tapping connection studs will now be described in more detail. As Figure 2 、 3As shown in FIGS. 26 and 27, the flange connection assembly 1600 includes an outer edge 1641. The outer edge 1641 includes the plurality of receiving structures 1650. Each receiving structure 1650 is aligned with one of the self-tapping connection studs 1200.

[0086] Now referring to Figures 18-26 , each self-tapping connection stud 1200 includes a head portion 1210, a shank portion 1220, self-tapping threads 1230, and a cutting body 1240. The head portion 1210 includes a drive head 1211, and the drive head 1211 is configured to be engaged and rotated by the outer drill string 1430. The head portion 1210 is configured to be fixed within the bushing structure 1121 before being engaged with the outer drill string 1430. The head portion 1210 also includes an upper flange portion 1212. In at least one instance, the upper flange portion 1212 is also configured to be pushed downward by the outer drill string 1430 to linearly advance the self-tapping connection stud 1200. The head portion 1210 also includes a main head flange (or locking collar) 1213, and the main head flange 1213 is configured to abut against the flange connection assembly 1600 when the self-tapping connection stud 1200 is installed into the hull.

[0087] Primarily referring to Figure 18 , the shank portion 1220 extends downward from the main head flange 1213 to the self-tapping threads 1230. Between the shank portion 1220 and the self-tapping threads 1230, a break point (or discontinuity) 1221 is provided, which will be discussed in more detail below. The self-tapping threads 1230 include a tapered thread portion 1231 and a relief groove 1232. The self-tapping threads 1230 are configured to be driven into the hull to fix the self-tapping connection stud 1200, and thus the flange connection assembly 1600, to the hull. The cutting body 1240 includes a tip 1241 and is configured to cut a hole in the hull for the self-tapping threads 1230 to engage.

[0088] Each receiving structure 1650 includes a receiving body 1651 and a bushing 1652 positioned at the top and inside of the receiving body 1651. Overall, the receiving body 1651 and the bushing 1652 define a receiving cavity 1653. In at least one instance, the receiving body is a conventional metal pipe fitting, for example, to provide a rigid structure on which the self-tapping connection stud 1200 can be fastened. In at least one instance, the pipe fitting is welded to the outer edge 1641. Any suitable rigid structure can be used. In at least one instance, the bushing 1652 includes a rubber material. Any suitable material can be used to manufacture the bushing 1652. The bushing 1652 is configured to hold its position in Figures 19-26in the position shown in order to maintain the receiving cavity 1653 throughout the installation of the self-tapping attachment stud 1200. Maintaining a receiving cavity 1653 of constant volume throughout the installation of the self-tapping attachment stud 1200 ensures space to prevent debris and / or waste fluid from interfering with the installation of the self-tapping attachment stud 1200. For example, as the self-tapping attachment stud 1200 is driven into the hull 1001, debris can freely float within the receiving cavity 1653 during installation rather than becoming trapped between the self-tapping attachment stud 1200 and the hull 1001. In at least one instance, the volume of the receiving cavity 1653 is based on the predicted amount of debris from the installation of the self-tapping attachment stud 1200. For example, the volume of the receiving cavity 1653 is at least capable of accommodating the volume equal to the metal chips from the hull having the greatest thickness through which the stud 1200 will attempt to be installed.

[0089] In at least one instance, the bushing is rigidly supported within the receiving body 1651 rather than at the top and interior of the receiving body 1651. In such a case, the bushing can be configured to slide downward relative to the receiving body 1651 during the installation of the self-tapping attachment stud 1200. In at least one instance, the bushing is positioned near and / or at the bottom of the receiving body 1651 against the outer edge 1641 of the flange connection assembly 1600. In such a case, the downward force applied to the bushing enhances the seal to prevent fluid and / or debris from escaping through the hole drilled in the hull by the self-tapping attachment stud 1200.

[0090] Figures 18-24 illustrates the process of fully driving or installing the self-tapping attachment stud 1200 into the hull 1001 using the receiving structure 1650. For example, Figure 19 illustrates in connection with Figure 2 and Figure 3 the self-tapping attachment stud 1200 shown in an unactuated position. To drive the self-tapping attachment stud 1200 into the hull 1001, the outer drill rod 1430 engages the drive head 1211 ( Figure 20 ), and the self-tapping attachment stud 1200 is driven downward through the receiving structure 1650 to bring the cutting tip 1241 into contact with the hull 1001. At this position, the self-tapping threads 1230 are in sealing engagement with the bushing 1652, thereby initiating the seal between the bushing 1652 and the hull 1001. Once in contact with the hull 1001, the rotation and downward axial movement of the self-tapping attachment stud 1200 are continued to cut a hole in the hull 1001, where the self-tapping threads 1230 remain in sealing engagement with the bushing 1652 to prevent debris and / or waste fluid from escaping from the receiving cavity 1653 ( Figure 21 ).

[0091] As the self-tapping attachment stud 1200 is further driven into the hull 1001, the sealed engagement between the self-tapping attachment stud 1200 and the bushing 1652 transfers from the self-tapping threads 1230 to the shank 1220 ( Figure 22 ). Further axial movement and rotational actuation of the self-tapping attachment stud provides a sealed engagement between the shank 1220 and the bushing 1652 ( Figure 23 ). Finally, after the self-tapping attachment stud 1200 is fully driven against ( Figure 24 ) the receiving structure 1650 to secure the outer edge 1641 to the hull 1001, the outer drill string 1430 can be retracted and repositioned to drive another self-tapping attachment stud 1200 through another receiving structure 1650. During the installation of the self-tapping attachment stud 1200, the receiving cavity 1653 may have collected waste fluid and / or debris, and the fluid and / or debris will be trapped, for example, to prevent the release of the fluid and / or debris into the surrounding seawater.

[0092] As described above, the self-tapping attachment stud 1200 may break and / or fail during installation. For any number of reasons, the stud 1200 may break and / or fail. For example, unpredictable hull material (a hull that is harder than expected), unpredictable hull thickness (a hull that is thicker than expected), manufacturing irregularities of the self-tapping attachment stud, and interfering objects within the hull and / or hull interior that the cutting tip 1241 hits may all increase the risk of failure of the self-tapping attachment stud during installation. Failure of the stud may result in the unexpected escape of waste fluid and / or debris. The self-tapping attachment stud 1200 and the receiving structure 1650 are configured to address these issues.

[0093] Turning Figure 25 , a self-tapping attachment stud 1200 in a first failure configuration is shown. A break point 1221 is provided on the attachment stud 1200 to direct or isolate the mechanical failure of the self-tapping attachment stud 1200 to the location of the break point 1221 in the event of failure of the self-tapping attachment stud 1200. Isolating the failure of the self-tapping connection can reduce the likelihood of failure of the self-tapping attachment stud 1200 at other locations, where failure would increase the risk of leakage of waste fluid and / or debris. In addition, the bushing 1652 is configured to hold the head portion 1210 and the shank 1220 after failure in order to maintain the sealed receiving cavity 1653 and trap any waste fluid and / or debris that escapes during the installation of the self-tapping attachment stud 1200.

[0094] Turning Figure 26, showing the self - tapping connection stud 1200 in a second failure configuration. In this case, the break point is within the self - tapping thread 1230. For reasons similar to those listed above regarding the first failure configuration, this failure may also be less severe than failures at other locations. A sealed engagement is maintained between the bushing 1652 and the self - tapping thread 1230, and the bushing 1652 holds the position of the failed portion of the self - tapping connection stud 1200 after failure. Although the hole is not completely drilled during this failure, the metal chips generated during the drilling of a part of the hole can be trapped in the receiving cavity 1653.

[0095] Referring again to Figures 1-3 , after the flange connection assembly 1600 is fixed to the hull by the self - tapping connection stud 1200, the rotary fluid actuator 1410 and the second linear fluid actuator 1440 are actuated in concert to linearly advance and rotate the main drill pipe 1450. As discussed in more detail below, the main drill pipe 1450 is configured to cut or drill a main hole in the hull using the pilot bit 1451 and the annular cutter 1452. In at least one instance, the main drill pipe 1450 is gear - driven within the transmission 1415 according to the torque and speed requirements for drilling the main hole in the hull for fluid extraction, while the outer drill pipe 1430 is gear - driven within the transmission 1415 according to different torque and speed requirements for driving the self - tapping connection stud 1200 into the hull. In at least one instance, greater torque and lower speed are optimal for the main hole, while limited torque and greater speed are optimal for driving the self - tapping connection stud 1200 into the hull. Any suitable combination of torque and speed specifications can be used.

[0096] In at least one instance, multiple flange connection assemblies 1600 are configured to be used with the underwater drilling system 1000 to provide multiple fluid access points through the hull. Thus, referring again to Figures 1-3 and Figures 27-30 , the flange connection assembly 1600 is capable of being coupled to and separated from the frame connection assembly 1130 of the frame 1100, and / or capable of being locked to and unlocked from the frame connection assembly 1130 by the locking assembly 1160 of the frame 1100. In at least one instance, this occurs on the ship. In at least one instance, this occurs at the drilling site. In at least one instance, this is performed manually. In at least one instance, this is performed by an ROV.

[0097] Referring mainly to Figures 27-30 , the frame connection assembly 1130 includes a male connection portion 1140 fixedly attached to the lower platform 1120. The male connection portion 1140 includes a support flange 1141 and a male pipe end 1142, and the male pipe end 1142 is configured to be received within the flange connection assembly 1600 as discussed in more detail below.

[0098] Main reference Figure 29 , the flange connection assembly 1600 includes a female connection portion 1610 configured to receive the male connection portion 1140 therein, a knife switch hole 1630, and a lower connection portion 1640 including an outer edge 1641. The female connection portion 1610 includes a connection flange 1620 and a central hole section 1621 configured to receive the male pipe end 1142 of the male connection portion 1140. In at least one instance, the central hole section 1621 includes a machined inner surface configured to mate and seal with the outer surface of the male connection portion 1140. In at least one instance, the outer surface of the male connection portion 1140 is also machined to ensure a tight sealing interface between the inner surface of the central hole section 1621 and the outer surface of the male connection portion 1140. A gasket 1695 is also disposed between the male connection portion 1140 and the central hole section 1621. In at least one instance, the gasket 1695 is positioned in a groove of the male connection portion 1140. In at least one instance, the gasket 1695 is positioned in a groove of the inner surface of the central hole section 1621. The connection flange 1620 includes a mating surface 1622 configured to mate with a corresponding mating surface 1143 of the male support flange 1141. The connection flange 1620 further includes a plurality of slots 1623 defined therein.

[0099] To couple the flange connection assembly 1600 to the frame connection assembly 1130, the locking assembly 1160 is placed in its unlocked configuration. The locking assembly 1160 includes a linear fluid actuator 1163 and a locking ring 1161, and the locking ring 1161 includes a plurality of locking claws 1162. The locking ring 1161 is axially fixed to the frame connection assembly 1130; however, the locking ring 1161 is capable of freely rotating relative to the frame connection assembly 1130 between a locked position and an unlocked position. The linear fluid actuator 1163 is actuated to rotate the locking ring 1161 relative to the frame connection assembly 1130 between the locked position and the unlocked position.

[0100] Once the locking ring 1161 is in its unlocked position, the slots 1623 of the connection flange 1620 are axially aligned with the locking claws 1162 of the locking ring 1161, and the flange connection assembly 1600 is brought into engagement against the support flange 1141, with the locking claws 1162 passing through the slots 1623. At this time, main reference Figure 28, the linear fluid actuator 1163 is actuated to rotate the locking ring 1161 to the locked position, thereby rotating the locking jaw 1162 relative to the coupling flange 1620, and thus rotating the rotation slot 1623, whereby the jaw 1162 and the slot 1623 are misaligned. When in its locked position, the locking ring 1161 is positioned such that the locking jaw 1162 axially constrains the flange connection assembly 1600 relative to the frame connection assembly 1130. To remove the flange connection assembly 1600 from the frame connection assembly 1130, the locking ring 1161 is rotated by the linear fluid actuator 1163 to its unlocked position to axially realign the locking jaw 1162 and the slot 1623 such that the male connection portion 1140 can be removed from the female connection portion 1610.

[0101] As Figure 28 can be seen, the male connection portion 1140 includes a chamfered edge 1144. Such a chamfered edge can assist in inserting the male connection portion 1140 into the female connection portion 1610. In at least one instance, the male connection portion 1140 is axially constrained not only by the mating surface 1143 of the male support flange 1141 but also by a shoulder 1624 defined within the coupling flange 1620. In at least one instance, the male connection portion 1140 is axially constrained only by the shoulder 1624.

[0102] To prevent relative rotation between the flange connection assembly 1600 and the remainder of the underwater drilling system 1000, a guiding system is employed. With primary reference Figures 27-29 , the guiding system includes guiding jaws 1390 extending from each housing body member 1321 and corresponding guiding posts 1642 extending from the lower connection portion 1640. Each jaw 1390 includes an introduction slot portion 1391 configured to capture the post 1642 and a retaining slot portion 1392. The introduction slot portion 1391 includes a tapered profile to guide a closer fit between the incoming post 1642 and the jaw 1390. Each post 1642 includes an introduction surface 1643 configured to assist in aligning the post 1642 with the introduction slot portion 1391. When the post 1642 is positioned within the retaining slot portion 1392, relative rotation between the attachment leg 1300 and the flange connection assembly 1600 is prevented. When removing the underwater drilling system 1000 from the installed flange connection assembly 1600, the jaw 1390 slips off the post 1642.

[0103] Referring to Figure 28, in various situations, the manual unlock actuator 1170 is connected to the locking assembly 1160 to allow manual rotation of the locking ring 1161. For example, in an emergency, such an actuator can be used to require disengagement or unlocking of the frame coupling assembly 1130 and the flange connection assembly 1600. In at least one instance, the unlock actuator 1170 is configured to release hydraulic pressure from the linear fluid actuator 1163 to automatically rotate the locking ring 1161 back to its unlocked position.

[0104] Main reference Figure 29 , after the flange connection assembly 1600 is fixed to the hull and the main hole is drilled, the knife gate 1660 of the flange connection assembly 1600 is actuated to seal the flange connection assembly 1600 to prevent additional fluid from flowing out of the main hole of the sunken ship except for waste liquid and / or debris that may escape from the ship during the drilling of the main hole, and to allow the discharge of the waste liquid within the flange connection assembly 1600, which will be discussed in detail below. When the knife gate 1660 is actuated, the knife gate 1660 divides the drill cavity into an upper drill cavity and a lower drill cavity through which the drill pipe passes to drill the main hole. In at least one instance, the knife gate 1660 is actuated by a linear fluid actuator.

[0105] The knife gate 1660 includes a gate frame 1661 and a knife gate hole 1630 extending from the gate frame 1661. The knife gate hole 1630 is fixed between the coupling flange 1620 and the lower coupling portion 1640. In at least one instance, the female coupling portion 1610, the knife gate hole 1630, and the lower coupling portion 1640 are integrally formed. The knife gate hole 1630 includes a knife groove 1631 extending horizontally across half of the knife gate hole 1630. The knife gate 1660 further includes a sealing knife gate 1670 slidably supported within the gate frame 1661 and configured to be received within the groove 1631 to provide a fluid seal between the female coupling portion 1610 and the lower coupling portion 1640. In at least one instance, the knife gate 1670 includes a semi-circular end to save space within the flange connection assembly 1600 and maximize the effectiveness of the seal provided by the knife gate 1660 by restricting the profile of the knife gate 1670 to correspond to the interior of the knife gate hole 1630 and allowing the edges of the semi-circular end to press against the interior of the knife gate hole 1630. In at least one instance, a rubber cap is provided on the semi-circular end to further enhance the fluid seal of the knife gate 1670 within the knife gate hole 1630. The sealing knife gate 1670 can include any suitable material, such as metal, plastic, wood, and / or rubber.

[0106] After the knife switch 1660 is closed, the waste liquid and / or debris escaping from the main hole during the drilling of the main hole are trapped in the upper drilling cavity defined in the male connection part 1140. Now, the waste liquid and / or debris in the upper drilling cavity are discharged from the upper drilling cavity into the waste box assembly 1800 of the underwater drilling system 1000, in an attempt to reduce or eliminate the escape of the waste liquid and / or debris into the surrounding medium (such as seawater) when the rest of the underwater drilling system 1000 is separated from the installed connection flange assembly 1600.

[0107] Now, the discharge of the waste liquid and / or debris from the upper drilling cavity into the waste box assembly 1800 will be described. With primary reference Figures 31-36 , the waste liquid "WF" and / or debris are configured to be discharged from the upper drilling cavity into the waste box assembly 1800. As Figures 31-36 can be seen, a drilling cavity 1850 is defined within the frame connection assembly 1130 and the flange connection assembly 1600 when they are operably connected to each other by the above-described locking assembly 1160. The drilling cavity 1850 is defined as a chamber within the frame connection assembly 1130 and the flange connection assembly 1600 through which a drill bit passes to drill the main hole in the hull 1001.

[0108] The waste box assembly 1800 includes a waste box 1810 mounted to the frame 1100. The waste box 1810 is configured to collect and store the waste liquid WF and / or debris discharged from the drilling cavity 1850. The waste box 1810 includes a vent 1811 and a volume rod 1820. The volume rod 1820 is configured to move relative to the housing of the waste box 1810 as the waste liquid WF and / or debris push the volume rod 1820 to move upward relative to the housing.

[0109] As Figure 31 can be seen, the main drill rod 1450 is shown in the unactuated position and the main hole has not been drilled yet. Before drilling the main hole, the main drill rod 1450 is linearly translated slightly towards the hull 1001 ( Figure 32 ), to increase the pressure within the drilling cavity 1850 by increasing the material volume of the main drill rod 1450 within the drilling cavity 1850. Increasing the pressure at this stage is to test the seal of the drilling cavity 1850. The pressure is indicated by a pressure gauge 1833. In at least one instance, for example, when the main drill rod 1450 is held in the unactuated position, a fluid such as seawater is pumped into the drilling cavity 1850 to increase the pressure within the drilling cavity 1850 and test the seal. In at least one instance, the pressure within the drilling cavity 1850 is regulated and / or controlled by a check valve.

[0110] Once sufficient seal is detected, the main drill rod 1450 is driven through the drilling cavity 1850 and into the hull 1001 ( Figure 33), to drill a main hole in the hull 1001 using the guide bit 1451 and the annular cutter 1452. In at least one instance, drilling the main hole and retracting the main drill pipe 1450 to the initial position causes waste liquid WF and / or debris to leak into the drill cavity 1850. Once the main hole is drilled, the main drill pipe 1450 retracts to its initial position ( Figure 34 ), and the knife gate 1660 is actuated to sealingly divide the drill cavity 1850 into an upper drill cavity 1851 and a lower drill cavity 1852. As Figure 34 can be seen, waste liquid WF and / or debris are present in the upper drill cavity 1851 and the lower drill cavity 1852. Now, the waste liquid WF and / or debris can be discharged from the upper drill cavity 1851 and into the waste bin 1810.

[0111] Referring to Figure 35 , to remove the waste liquid WF and / or debris in the upper drill cavity 1851, the pump 1830 pumps seawater "W" into the upper drill cavity 1851 through the check valve 1831, which is configured to prevent the fluid from flowing back from the upper drill cavity 1851 towards the pump. In at least one instance, before, during, and / or after pumping seawater W into the upper drill cavity 1851, the main drill pipe 1450 rotates to agitate the waste liquid WF and seawater W in the upper drill cavity 1851. In at least one instance, when the waste bin 1810 is filled with the waste liquid WF, the main drill pipe 1450 continuously rotates.

[0112] Pumping seawater W into the upper drill cavity 1851 causes the waste liquid WF and / or debris to be removed into the waste bin 1810 via the outlet 1832 that is in fluid communication with the frame coupling assembly. In at least one instance, the outlet 1832 is in fluid communication with the male coupling portion 1140. The outlet 1832 includes a check valve 1834, which is configured to prevent the fluid from flowing back from the waste bin 1810 towards the upper drill cavity 1851. In at least one instance, the check valve 1834 is further configured to regulate and / or control the pressure in the drill cavity 1850 and / or the upper drill cavity 1851.

[0113] Still referring to Figure 35 , as the waste liquid WF and / or debris flow into the waste bin 1810, the volume rod 1820 is pushed upward by the plunger head 1821 of the volume rod 1820 because the waste bin 1810 is filled with the waste liquid WF. In at least one instance, air can be trapped below the plunger head 1821 in the waste bin 1810. The plunger head 1821 includes a check valve 1822, which is configured to automatically remove the trapped air in the waste bin 1810. In at least one instance, when the underwater drilling system 1000 is brought to the water surface, the trapped air in the waste bin 1810 may expand. The air will be discharged through the check valve 1822. The vent 1811 is further configured to remove fluid (e.g., seawater) from the waste bin 1810 when the volume rod 1820 is pushed upward by the waste liquid WF.

[0114] In at least one instance, the volume rod 1820 is configured to be pulled upward during fluid clearance from the upper drill cavity 1851 by a fluid linear actuator to suck out the waste fluid WF from the upper drill cavity 1851. The suction force can be applied by the plunger head 1821 and can supplement the pumping of water into the upper drill cavity 1851 by the pump 1830. In at least one instance, the pump is not used and ambient water can be sucked into the upper drill cavity 1851 by the waste box 1810 through a check valve. In at least one instance, a vacuum pump is used within the waste box 1810 to apply further suction force to the fluid in the upper drill cavity 1851.

[0115] In at least one instance, the waste box 1810 is sized to accommodate three times the volume of the upper drill cavity 1851. In this case, the waste fluid WF within the upper drill cavity can be cleared three times before removing the underwater drilling system 1000 from the flange connection assembly 1600 to ensure that clean residual fluid (e.g., as close to 100% seawater as possible) remains within the upper drill cavity 1851. The waste box 1810 can include any suitable size. The waste box 1810 also includes a transparent housing to facilitate visual inspection of the contents of the waste box during clearance of the upper drill cavity 1851. In at least one instance, the contents of the waste box 1810 can be monitored by and / or through an ROV.

[0116] Once the waste box 1810 is full and / or the clearance process is complete, the male coupling portion 1140 and the flange connection assembly 1600 are disengaged to remove the underwater drilling system 1000 from the flange connection assembly 1600. The underwater drilling system 1000 containing the full waste box 1810 can be brought to the surface to empty the waste box and / or rinse the waste box for subsequent use. In at least one instance, the waste box 1810 allows for sampling of the collected waste fluid WF prior to the complete fluid extraction process. Additionally, at this point, a hose assembly can be connected to the flange connection assembly 1600, the knife gate 1660 can be opened, and fluid can be pumped out from the hull (e.g., through the complete fluid extraction process).

[0117] In various cases, air trapped within the hull may be encountered during drilling of the primary hole by the underwater drilling system 1000. This air can flow into the underwater hose and / or components of the underwater drilling system 1000, and when the underwater drilling system 1000 is brought to the surface, this air can rapidly expand and potentially cause overpressure in the underwater hose and / or components of the underwater drilling system 1000. This rapid expansion can damage the underwater hose and / or components of the underwater drilling system 1000.

[0118] Main reference Figure 37 and Figure 38, the underwater drilling system 1000 utilizes an automatic exhaust valve assembly 1900 to automatically ventilate or discharge the air encountered during drilling the main hole in the hull. The automatic exhaust valve assembly 1900 is in fluid communication with the upper drilling cavity 1851 through an outlet 1832 ( Figure 31 ). In at least one instance, the automatic exhaust valve assembly 1900 is in fluid communication with the upper drilling cavity 1851 through a female coupling portion 1610 ( Figure 30 ) and / or a male coupling portion 1140 ( Figure 30 ). In any case, the air flowing out of the hull and into the upper drilling cavity 1851 is configured to be automatically discharged through the outlet 1832 via an inlet exhaust pipeline 1901.

[0119] The automatic exhaust valve assembly 1900 includes an inlet shaft 1920 in fluid communication with the inlet exhaust pipeline 1901 and a head portion 1930 in fluid communication with the inlet shaft 1920, and the air from the inlet exhaust pipeline 1901 is configured to be discharged through the inlet shaft. The inlet shaft 1920 and the head portion 1930 are pivotally connected to the frame 1100 and / or the inlet exhaust pipeline 1901 through a fluid pivot coupling 1910, thereby allowing the inlet shaft 1920 and the head portion 1930 to allow the head portion 1930 to be aligned to the shallowest position through an external float member 1940 while maintaining fluid communication. In at least one instance, the inlet exhaust pipeline 1901 includes a rigid fluid pipeline and / or a flexible fluid pipeline. In at least one instance, the inlet shaft 1920 includes a rigid fluid shaft and / or a flexible fluid shaft. In at least one instance, the fluid pivot coupling 1910 includes a hydraulic swivel elbow.

[0120] Main reference Figure 38 , the head portion 1930 includes an external float member 1940, which is configured to facilitate the head portion 1930 towards the balanced pressure position (e.g., the shallowest position within the ocean) when the underwater drilling system 1000 is attached to the hull. The head portion 1930 further includes an internal valve chamber 1950 and a shuttle valve body 1960 that can move up and down within the internal valve chamber 1950. The internal valve chamber 1950 includes a chamber wall 1951 that defines a chamber cavity 1952. The shuttle valve body 1960 can move freely within the chamber cavity 1952 and move relative to the chamber wall 1951. As Figure 38 can be seen, the head portion 1930 includes a fluid inlet through which waste liquid and air can enter the chamber cavity 1952 from the inlet shaft 1920.

[0121] The shuttle valve body 1960 includes an internal float member 1961 and an internal passage 1962 that includes a passage wall 1963. The passage 1962 is configured to allow fluid and / or air to flow freely therethrough from the chamber 1952. The shuttle valve body 1960 also includes an upper vent head 1964 that includes a vent opening 1965 defined therein, and the vent opening is configured to allow air in the passage 1962 to flow therethrough and into the upper portion of the chamber 1952. The head portion 1930 also includes a bottom plate 1931 and a vented top plate 1970 that includes a vent opening 1971, and the vent opening is configured to be sealed and unsealed by the flange plug 1966 of the shuttle valve body 1960, as discussed in more detail below.

[0122] Air and / or waste fluid is configured to flow into the chamber 1952 during automatic exhaust from the drill cavity. Since the waste fluid is denser than air, the waste fluid is configured to accumulate at the bottom of the chamber 1952, while the air passes through the waste fluid into the chamber 1952, up into the passage 1962 and through the vent opening 1965 into the upper portion of the chamber 1952. The waste fluid is configured to push the shuttle valve body 1960 upward within the chamber 1953. When the pressure buildup of air escaping into the upper portion of the chamber 1952 exceeds the pushing pressure applied to the shuttle valve body 1960 by the internal float member 1961, the air pressure pushes the shuttle valve body 1960 downward. This downward movement of the shuttle valve body 1960 causes the flange plug 1966 to move away from the top plate 1970, thereby allowing the trapped air to be discharged through the vent opening 1971 to the ocean and / or ambient air. In at least one instance, any air encountered within the hull during drilling of the main hole is configured to be continuously discharged from the system through the automatic exhaust valve assembly 1900.

[0123] In at least one instance, a check valve (or non-return valve) prevents waste fluid from flowing into the head portion 1930. In such an instance, the automatic exhaust valve assembly 1900 operates in a manner similar to that described above; however, the pressure buildup of air in the upper portion of the chamber cavity 1952 only needs to exceed the pressure buildup of air below the shuttle valve body 1960 to cause the shuttle valve body 1960 to move downward to release the trapped air. In at least one instance, when the chamber cavity 1952 is filled with air, the shuttle valve body 1960 is configured to slide to the bottom head portion 1930, and the air is released through the vent opening 1971. In any case, waste fluid is prevented from escaping from the automatic exhaust valve assembly.

[0124] Once removed from the installed flange connection assembly 1600, the remainder of the underwater drilling system 1000 can be transported back to the surface, for example, by an ROV, to reinstall the buoyancy member 1005, reload additional flange connection assemblies, clean and / or flush the waste cartridge assembly 1800, and prepare for the installation of the next flange connection assembly. In at least one instance, the buoyancy member 1005 is reinstalled onto the frame 1100 before the above steps occur. In at least one instance, another flange connection assembly is aligned with the male coupling portion 1140 of the frame 1100, and the locking assembly 1160 locks the male coupling portion 1140 and the new flange connection assembly.

[0125] The fluid actuators disclosed herein can include any suitable fluid actuators, such as rotary hydraulic actuators, linear hydraulic actuators, rotary pneumatic actuators, linear pneumatic actuators, hydraulic drills, and / or pneumatic drills, etc. In at least one instance, any of the fluid actuators disclosed herein can be replaced with electric actuators, such as rotary electric actuators, linear electric actuators, and / or electric drills.

[0126] The fluid used within the fluid actuator can include any suitable actuator fluid, such as hydraulic fluid and / or air.

[0127] Figure 39 is a schematic diagram of a control system 4000 that includes an above-water component 4100 and a below-water component 4200 of a drill assembly 4220. The above-water component 4100 and the below-water component 4200 cooperate to allow a user to operate the drill assembly 4220, for example, from a ship. The above-water component 4100 is positioned, for example, on a ship and is configured to send power, send and receive hydraulic fluid, and send and receive data signals to the below-water component 4200. The below-water component 4200 includes a transport center 4210 that is configured to transport the drill assembly 4220 from the ship to a drilling site and also control the transmission of fluid flow, electrical signals, and data signals between the above-water component 4100 and the drill assembly 4220. For example, once the transport center 4210 is positioned, for example, on the seabed near the drilling site, the drill assembly 4220 is removed from the transport center 4210 and positioned at a target drilling location on a sunken ship.

[0128] The surface component 4100 includes a control interface 4110, a power control box 4120, and a hydraulic power pack 4130, which are configured to deliver power, hydraulic fluid, and data signals to the subsea component 4200. The control interface 4110 may include, for example, a computer. The operator uses the control interface 4110 to send commands to the power control box 4120 in the form of data signals, and the power control box conveys the commands and power to the subsea component 4200. The hydraulic power pack 4130 is positioned in the hydraulic circuit of the system 4000 to control the flow of hydraulic fluid through the subsea component 4200. The surface component 4100 also includes an optional system that includes a pump 4140, which is configured to deliver fluid to a borehole location to jet away debris at the borehole location. All electrical and fluid transfers between the surface component 4100 and the subsea component 4200 are achieved through transmission cables and hoses. Data signals can be transmitted through, for example, Ethernet cables, fiber optic cables, and / or coaxial cables.

[0129] The transfer center 4210 is moored to the surface component 4100 and the rig assembly 4220 to control the transfer of power, hydraulic fluid, data signals, and electrical signals between the surface component 4100 and the rig assembly 4220. The transfer center 4210 includes a valve box 4211 and a segregated electrical compartment (or cavity) 4212. The valve box is configured to house non-fluid-sensitive transfer components, and the segregated electrical compartment is configured to house fluid-sensitive transfer components. The valve box 4211 includes internal fluid valves and electronics, such as proportional valves, pressure relief valves, pressure sensors, valve control modules, and solid state relays. The segregated electrical compartment 4212 includes a dry environment for housing a control circuit 4213, such as a programmable logic controller. The programmable logic controller 4213 is connected to the electronics within the valve box 4211, such as relays, sensors, and valve control modules. The programmable logic controller 4213 is also connected to the surface component to send and receive data signals to and from the control interface 4110, such that the programmable logic controller 4213 can communicate with the control interface 4110 to receive instructions from the control interface 4110 and convey information to the control interface 4110. Instructions can be received from the control interface 4110 that tell the programmable logic controller 4213 to activate relays and / or adjust valves within the valve box 4211 with a remote control module. Information can be conveyed to the control interface 4110 that corresponds to information collected by sensors within the valve box 4211.

[0130] The control circuit may include a microcontroller that includes one or more processors (e.g., a microprocessor, a microcontroller), and the processor is coupled to at least one memory circuit. The memory circuit stores machine-executable instructions that, when executed by the processor, cause the processor to execute machine instructions to implement the various processes described herein. The processor may be any of a number of single-core or multi-core processors known in the art. The memory circuit may include volatile and non-volatile storage media. The processor may include an instruction processing unit and an arithmetic unit. The instruction processing unit may be configured to receive instructions from the memory circuit.

[0131] The drill assembly 4220 includes a number of components, some of which require power, electrical signal transmission, fluid transmission, and / or data transmission. The drill assembly 4220 includes a mounting system that includes a plurality of magnets 4221, which may be, for example, electromagnets, to secure the drill assembly 4220 to a magnetic material (e.g., the hull of a ship) as further described herein. The electromagnets 4221 receive power from the power control box 4120 through the valve box 4211. To activate the electromagnets 4221, power can be delivered when an instruction from the control interface 4110 is sent to the programmable logic controller 4213 to switch the relay in the valve box 4211 to the open state. Similarly, to deactivate the electromagnets 4221 and detach the drill assembly 4220 from the hull of the ship, power can be cut off when an instruction from the control interface 4110 is sent to the programmable logic controller 4213 to switch the relay in the valve box 4211 to the closed state.

[0132] The drill assembly 4220 further includes a drilling system, as discussed in more detail herein, that includes a linear actuator system 4223 and a drill bit drive system 4224, which is configured to move up and down by the linear actuator system 4223 and is configured to drive a self-tapping drill bit assembly into the hull of the ship. The linear actuator system 4223 may include, for example, a hydraulic cylinder that requires hydraulic fluid to flow into and out of the hydraulic cylinder to move the hydraulic cylinder, thereby causing the drill bit drive system 4224 to move up and down. The hydraulic fluid is configured to flow between the hydraulic power pack 4130, the valve box 4211 in the transportation center 4210, and the hydraulic cylinder. To control the position of the drill bit drive system 4224, the valve control module in the valve box 4211 can adjust the valve configuration within the valve box 4211 according to instructions received from the programmable logic controller 4213 to regulate the flow of fluid to the hydraulic cylinder to actuate the hydraulic cylinder. The position of the drill bit drive system 4224 can be monitored by monitoring the pressure in the hydraulic cylinder fluid circuit with a pressure sensor in the valve box 4211. The monitored pressure can be transmitted to the control interface 4110 so that the operator is provided with the position of the drill bit drive system 4224 during the operation of the drill assembly 4220.

[0133] The drill drive system 4224 is configured to drill a self-tapping drill bit assembly into the hull. The drill drive system 4224 may include a hydraulic drill. For example, hydraulic fluid is required to flow into and out of the hydraulic drill to drive the hydraulic drill and thus cause the self-tapping drill bit assembly to rotate clockwise and counterclockwise. The hydraulic fluid is configured to flow between the hydraulic power pack 4130, the valve box 4211 in the transportation center 4210, and the hydraulic drill. To control the rotation of the hydraulic drill, the valve control module in the valve box 4211 can adjust the valve configuration inside the valve box 4211 based on instructions received from the programmable logic controller 4213 to regulate the fluid flow to the hydraulic drill to actuate the hydraulic drill. The amount of resistance experienced by the hydraulic drill during drilling can be monitored by monitoring the pressure in the hydraulic drill fluid circuit with a pressure sensor in the valve box 4211 to monitor the pressure required to drive the drill bit assembly into the hull. The monitored pressure can be sent to the control interface 4110 so that the operator can adjust the drill drive system 4224 and / or the linear actuator system 4223 accordingly. For example, the operator can reduce the speed of the hydraulic drill and / or raise the drill drive system 4224 to reduce the resistance experienced by the hydraulic drill.

[0134] The drilling assembly 4220 includes various other components. For example, the drilling assembly 4220 includes: an underwater camera 4225 to allow the operator to see the drilling location; an underwater light 4226 to illuminate the drilling location for the camera to see; and one or more proximity sensors 4222 configured to determine the relative position between the drilling assembly 4220 and the hull and / or the relative position between the drill bit assembly and the hull during drilling. The underwater camera 4225, the underwater light 4226, and the one or more proximity sensors 4222 require power from the transportation center 4210. The underwater camera 4225 requires a data signal to be transmitted between the underwater camera 4225 and the control interface 4110 so that the operator can see the drilling location through the control interface 4110. The one or more proximity sensors 4222 require electrical and / or data signal transmission so that the programmable logic controller 4213 can send the relative position between the components to the control interface 4110.

[0135] The various components 4000 of the system can include analog components and / or digital components. For example, in the case of using an analog sensor, there is no need to send and receive digital data from the analog sensor, so the system 4000 can be simplified. In the case of using a digital sensor, digital data needs to be sent to and from the digital sensor. In various cases, both analog components and digital components are used, but any suitable arrangement of analog components and digital components can be adopted. Some analog components can provide greater simplicity to the system. For example, some digital components can provide higher accuracy than their analog counterparts. In addition, where digital components are used, the required analog-to-digital conversion of signals can be performed in a converter installed on a ship to further simplify the system containing digital components.

[0136] The drilling assembly 4220 can also include a water jet nozzle 4227 configured to receive fluid (such as water) from a pump 4140 to eject debris at the drilling location. The system bypasses the transportation center 4210 and the control interface 4110 to increase the simplicity of the system 4000; however, for example, the water jet nozzle 4227 and the pump 4140 can be integrated with other components to increase the controllability of the water jet nozzle 4227 and the pump 4140.

[0137] Any transmission lines (such as electrical cables and fluid hoses) in the system 4000 can be attached to the components to which they are connected and can be detached from the components to which they are connected, so that if a component needs to be replaced and / or repaired, the component can be replaced quickly and / or easily. The system 4000 can also include various non-detachable transmission lines to reduce the possibility of leakage caused by some detachable / attachable interfaces. The system 4000 can include detachable / attachable transmission lines as well as non-detachable transmission lines.

[0138] Example

[0139] Example Group 1:

[0140] Example 1 - An underwater drilling assembly, comprising: a drilling assembly; a connecting flange assembly configured to be attached to the hull of a ship through the drilling assembly, wherein the connecting flange assembly includes a plurality of guiding lugs; and a frame supporting the drilling assembly. The frame includes a lower platform, and the lower platform includes attaching legs extending therefrom, wherein the attaching legs are configured to attach the underwater drilling assembly to the hull of the ship. Each attaching leg includes a fluid actuator, the fluid actuator includes an output shaft, an extendable leg assembly attached to the output shaft, a suction cup base attached to the extendable leg assembly through a ball-and-socket joint; and a guiding flange, the guiding flange includes a groove configured to receive one of the guiding lugs of the connecting flange assembly.

[0141] Example 2 - The underwater drilling assembly of Example 1, wherein the expandable leg assembly includes an upper leg portion and a lower leg portion, the upper leg portion being attached to the output shaft and movable by the output shaft, and the lower leg portion being spring-loaded against the upper leg portion to allow retraction of the upper leg portion relative to the lower leg portion when the output shaft retracts.

[0142] Example 3 - The underwater drilling assembly of Example 1 or 2, wherein the expandable leg assembly further includes an outer housing, the outer housing including a slot defined therein, wherein the lower leg portion includes a plunger attached to the lower leg by a pin, the pin extending radially outward from the plunger and being received in the slot.

[0143] Example 4 - The underwater drilling assembly of Example 1, 2 or 3, wherein the outer housing is fixedly attached to the lower platform.

[0144] Example 5 - The underwater drilling assembly of Example 1, 2, 3 or 4, wherein the connection flange assembly includes guiding fins, wherein the outer housing includes a guiding bracket extending from the lower end of the outer housing, the guiding bracket including a slot, and the guiding fins being positionable in the slot to guide the frame relative to the connection flange assembly.

[0145] Example 6 - The underwater drilling assembly of Example 1, 2, 3, 4 or 5, wherein the lower leg portion includes a plunger, the plunger including a head slidably supported within the upper leg portion, and a helical spring being located between the head and the bottom of the upper leg portion.

[0146] Example 7 - The underwater drilling assembly of Example 1, 2, 3, 4, 5 or 6, wherein the fluid actuator includes a hydraulic actuator.

[0147] Example 8 - The underwater drilling assembly of Example 1, 2, 3, 4, 5, 6 or 7, wherein the lower leg portion includes a spherical portion extending therefrom, the suction cup base including a socket, and the spherical portion being located within the socket.

[0148] Example 9 - An underwater drilling assembly frame including a frame and a plurality of legs configured to secure the frame to a hull, each leg including a suction cup base, a piston, an outer column fixedly attached to the frame, and an inner column positioned within the outer column, the inner column including an upper tube and a lower leg, the upper tube being fixedly attached to the piston, the lower leg being vertically constrained relative to the suction cup base, and the piston being actuable to expand the upper tube relative to the lower leg to pull the upper tube away from the hull.

[0149] Example 10 - The underwater drilling assembly frame of Example 9, wherein the lower leg is spring-loaded against the upper tube.

[0150] The underwater drilling assembly frame of Example 11 - Example 9 or 10, wherein the outer column includes a groove defined therein, wherein the lower leg includes a plunger attached to the lower leg by a pin, wherein the pin extends radially outward from the plunger and is received in the groove.

[0151] The underwater drilling assembly frame of Example 12 - Example 9, 10 or 11, further comprising a flange mountable to the hull, wherein the flange includes guiding fins, wherein the outer column includes a guiding bracket extending from the lower end of the outer column, wherein the guiding bracket includes a groove, and wherein the guiding fins can be positioned in the groove to guide the frame relative to the flange.

[0152] The underwater drilling assembly frame of Example 13 - Example 9, 10, 11 or 12, wherein the lower leg includes a plunger, wherein the plunger includes a head slidably supported within the upper tube, and wherein a helical spring is located between the head and the bottom of the upper tube.

[0153] The underwater drilling assembly frame of Example 14 - Example 9, 10, 11, 12 or 13, wherein the piston can be actuated by a hydraulic actuator.

[0154] The underwater drilling assembly frame of Example 15 - Example 9, 10, 11, 12, 13 or 14, wherein the lower leg includes a ball extending therefrom, wherein the suction cup base includes a socket, and wherein the ball is positioned within the socket.

[0155] Example 16 - A method for attaching an underwater drilling assembly to a hull, wherein the underwater drilling assembly includes a frame, a drilling assembly attached to the frame, and a connecting flange assembly including a gasket, wherein the frame includes a plurality of legs, and wherein each leg includes a suction cup base and an expandable leg assembly. The method includes lowering the underwater drilling assembly onto the hull and pressing the gasket against the hull to provide a seal with the hull through the connecting flange assembly, positioning each suction cup base of the plurality of legs against the hull, activating a suction force to fix each suction cup base to the hull, actuating a fluid actuator of each leg to pull an upper leg portion of the expandable leg assembly of each leg to increase the holding force of the plurality of legs, attaching the connecting flange assembly to the hull, and drilling a hole in the hull.

[0156] Example 17 - The method of Example 16, wherein actuating a fluid actuator of each leg to pull an upper leg portion of the expandable leg assembly of each leg includes pulling the upper leg portion upward relative to the hull and the lower leg portion of the expandable leg assembly.

[0157] Example 18 - The method of Example 16 or 17, wherein actuating a fluid actuator of each leg to pull an upper leg portion of the expandable leg assembly of each leg includes applying a pulling force to the suction cup base that is less than the suction force applied by the suction cup base.

[0158] The method of Example 19 - Example 16, 17, or 18, the method further comprising actuating a spring mechanism within the leg to allow each leg to move vertically independently of the hull.

[0159] Example Group 2:

[0160] Example 1 - An underwater drilling assembly, comprising a frame, a drilling assembly supported by the frame, and a self - tapping connecting stud actuatable by the drilling assembly, wherein the self - tapping connecting stud comprises a cutting body, a self - tapping thread configured to fix the self - tapping connecting stud to the hull, a shank portion, and a driveable head. The underwater drilling assembly further comprises a connecting flange assembly attachable to the hull through the self - tapping connecting stud, wherein the connecting flange assembly comprises a washer, a central hole, and an outer edge including a receiving structure, wherein the washer is positioned between the outer edge and the hull. The receiving structure comprises a sealing sleeve and a receiving cavity, wherein the self - tapping connecting stud is configured to pass through the receiving cavity when the self - tapping connecting stud is actuated by the drilling assembly to fix the outer edge to the hull, and wherein the sealing sleeve seals the receiving cavity when the self - tapping connecting stud passes through the sealing sleeve.

[0161] Example 2 - The underwater drilling assembly of Example 1, wherein the self - tapping connecting stud comprises a discontinuous portion configured to isolate a mechanical failure of the self - tapping connecting stud to the discontinuous portion.

[0162] Example 3 - The underwater drilling assembly of Example 1 or 2, wherein the discontinuous portion is positioned to ensure that if the self - tapping connecting stud fails, the discontinuous portion is located within the receiving cavity.

[0163] Example 4 - The underwater drilling assembly of Example 1, 2, or 3, wherein the receiving cavity is configured to accommodate debris leakage during actuation of the self - tapping connecting stud into the hull.

[0164] Example 5 - The underwater drilling assembly of Example 1, 2, 3, or 4, further comprising a plurality of self - tapping connecting studs, and wherein the outer edge comprises a plurality of receiving structures.

[0165] Example 6 - The underwater drilling assembly of Example 1, 2, 3, 4, or 5, wherein the drilling assembly is rotatable relative to the frame to drive each self - tapping connecting stud into the hull.

[0166] Example 7 - The underwater drilling assembly of Example 1, 2, 3, 4, 5, or 6, wherein the frame comprises a plurality of sleeve structures attached to the frame, and wherein each of the self - tapping connecting studs is held in a starting position by one of the plurality of sleeve structures.

[0167] Example 8 - The underwater drilling assembly of Example 1, 2, 3, 4, 5, 6, or 7, wherein the receiving structure comprises a self - sealing sleeve to seal the internal cavity of the receiving structure from ambient water when the self - tapping connecting stud is actuated through the self - sealing sleeve and into the receiving structure.

[0168] Example 9 - The underwater drilling assembly of Example 1, 2, 3, 4, 5, 6, 7, or 8, wherein the outer edge includes a first predetermined orifice, wherein the gasket includes a second predetermined orifice aligned with the first predetermined orifice, and wherein the self - tapping connection stud can be actuated to pass through the first predetermined orifice and the second predetermined orifice to engage the hull.

[0169] Example 10 - A fastening system for an underwater drilling assembly, wherein the fastening system includes a fastener and a port assembly, and the port assembly includes a gasket and a body that can be positioned against the hull. The body includes an outer edge, a sealing sleeve, and a receiving enclosure, wherein the receiving void is defined by the receiving enclosure and the sealing sleeve, wherein the fastener can move through the sealing sleeve, the receiving void, and the gasket, and wherein the receiving void is sealed when at least a portion of the fastener is positioned within the receiving void.

[0170] Example 11 - The fastening system of Example 10, wherein the fastener includes a discontinuous portion configured to isolate a mechanical failure of the fastener to the discontinuous portion.

[0171] Example 12 - The fastening system of Example 10 or 11, wherein the receiving void is configured to accommodate debris leakage during actuation of the fastener into the hull.

[0172] Example 13 - The fastening system of Example 10, 11, or 12, further including a plurality of fasteners, and wherein the outer edge includes a plurality of receiving enclosures aligned with the plurality of fasteners.

[0173] Example 14 - The fastening system of Example 10, 11, 12, or 13, wherein the outer edge includes a first predetermined orifice, wherein the gasket includes a second predetermined orifice aligned with the first predetermined orifice, and wherein the fastener can be actuated to pass through the first predetermined orifice and the second predetermined orifice to engage the hull.

[0174] Example 15 - A method of extracting fluid from a ship using an underwater drilling assembly, the method including positioning the underwater drilling assembly on the hull of the ship, actuating the leg assembly of the underwater drilling assembly to attach the underwater drilling assembly to the hull, driving at least one self - tapping stud through a connection flange assembly of the underwater drilling assembly including a receiving housing into the hull using a fluid drill of the underwater drilling assembly to fix the connection flange assembly to the hull, drilling a hole in the ship within an internal void defined in the connection flange assembly using the fluid drill, sealing the contents within the hole drilled by the fluid drill from ambient water using the connection flange assembly, disconnecting a portion of the underwater drilling assembly from the connection flange assembly, and extracting fluid through the connection flange assembly and the hole drilled by the fluid drill.

[0175] Example 16 - The method of Example 15, wherein driving at least one self - tapping stud with the fluid drill of the underwater drilling assembly further includes driving the at least one self - tapping stud into the receiving housing to seal the internal contents of the receiving housing from ambient water, and driving the at least one self - tapping stud into the hull until the at least one self - tapping stud is fully fixed to the hull, wherein the receiving housing houses the internal contents of the receiving housing throughout the driving of the at least one self - tapping stud.

[0176] Example 17 - The method of Example 15 or 16, wherein the at least one self - tapping stud includes a starting position and an ending position, at the starting position no part of the self - tapping stud is located within the corresponding receiving cavity, and at the ending position a discontinuous portion of the self - tapping stud is located within the corresponding receiving cavity.

[0177] Example 18 - The method of Example 15, 16 or 17, further including driving another self - tapping stud through another receiving housing into the hull with the fluid drill of the underwater drilling assembly.

[0178] Example Group 3:

[0179] Example 1 - An underwater drilling assembly, including a drilling assembly, a connection flange assembly configured to be attached to a hull by the drilling assembly, wherein the connection flange assembly includes an upper flange and a female coupling portion, and a frame supporting the drilling assembly. The frame includes a lower platform, attachment legs extending from the lower platform and configured to attach the underwater drilling assembly to the hull, a male coupling portion attached to the lower platform, wherein the male coupling portion is configured to be received by the female coupling portion, wherein the male coupling portion includes a lower flange, and a locking assembly attached to the frame, wherein the locking assembly is configured to lock and unlock the upper flange and the lower flange to couple and disassemble the male coupling portion and the female coupling portion.

[0180] Example 2 - The underwater drilling assembly of Example 1, wherein the locking assembly includes a locking ring configured to be rotated to couple and disassemble the upper flange and the lower flange.

[0181] Example 3 - The underwater drilling assembly of Example 1 or 2, wherein the locking ring includes a plurality of radial locking lugs, wherein the lower flange includes a plurality of slots configured to receive the radial locking lugs, and wherein the locking ring is rotatable relative to the upper flange to axially lock the male coupling portion and the connection flange assembly.

[0182] Example 4 - The underwater drilling assembly of Example 1, 2 or 3, wherein the locking assembly further includes a hydraulic actuator configured to rotate the locking ring relative to the frame, the male coupling portion and the connection flange assembly.

[0183] Example 5 - The underwater drilling assembly of Example 1, 2, 3 or 4, wherein the male coupling portion includes a sealing ring configured to fluid - seal the male coupling portion and the female coupling portion.

[0184] Example 6 - The underwater drilling assembly of Example 1, 2, 3, 4, or 5, wherein the connecting flange assembly further includes a guide post extending therefrom, the guide post configured to engage the attachment leg to prevent relative rotation between the connecting flange assembly and the lower platform.

[0185] Example 7 - The underwater drilling assembly of Example 1, 2, 3, 4, 5, or 6, wherein the male coupling portion includes a machined outer surface and the female coupling portion includes a machined inner surface, the machined inner surface configured to engage the machined outer surface.

[0186] Example 8 - The underwater drilling assembly of Example 1, 2, 3, 4, 5, 6, or 7, wherein the male coupling portion includes a chamfered tube edge receivable within the female coupling portion.

[0187] Example 9 - An assembly, comprising: a frame defining a first hole; a connecting flange defining a second hole, an axis passing through the first hole and the second hole, and a drill bit movable along the axis; and a locking device mounted to the frame, the locking device capable of rotating about the axis between a locked position and an unlocked position, at the locked position the connecting flange being fixed to the frame, at the unlocked position the connecting flange being disengaged from the frame such that the frame can be pulled away from the connecting flange when the connecting flange is fastened to the hull.

[0188] Example 10 - The assembly of Example 9, wherein the locking device includes a locking ring configured to be rotated to couple and decouple the connecting flange and the frame.

[0189] Example 11 - The assembly of Example 9 or 10, wherein the locking ring includes a plurality of radially extending locking lugs, the connecting flange including a plurality of slots configured to receive the radially locking lugs, and the locking ring rotatable relative to the frame and the connecting flange to axially lock the frame and the connecting flange together.

[0190] Example 12 - The assembly of Example 9, 10, or 11, further comprising a hydraulic actuator configured to rotate the locking ring relative to the frame and the connecting flange.

[0191] Example 13 - The assembly of Example 9, 10, 11, or 12, wherein the frame includes a male coupler including a seal configured to fluidly seal the frame and the connecting flange.

[0192] The component of Example 14 - Example 9, 10, 11, 12, or 13, wherein the frame includes a plurality of legs, and wherein the connecting flange further includes guide posts extending therefrom, the guide posts configured to engage the plurality of legs to prevent relative rotation between the connecting flange and the frame.

[0193] The component of Example 15 - Example 9, 10, 11, 12, 13, or 14, wherein the frame includes a male coupler, the male coupler including a machined outer surface, and wherein the connecting flange includes a female coupler, the female coupler including a machined inner surface, the machined inner surface configured to engage the machined outer surface.

[0194] The component of Example 16 - Example 9, 10, 11, 12, 13, 14, or 15, wherein the male coupler includes a chamfered tube edge receivable within the female coupler.

[0195] Example 17 - A method of extracting fluid from a sunken ship using an underwater drilling assembly, the underwater drilling assembly including a frame, a drilling assembly attached to the frame, and a connecting flange assembly, the method comprising: attaching the connecting flange assembly to the frame with a hydraulic actuator; lowering the underwater drilling assembly to the exterior of the sunken ship; actuating a leg assembly of the underwater drilling assembly to hold the frame of the underwater drilling assembly to the exterior; driving at least one self - tapping stud through the connecting flange assembly and into the exterior with a fluid drill of the underwater drilling assembly to secure the connecting flange assembly to the exterior; drilling a hole in the sunken ship with the fluid drill within an internal void defined in the connecting flange assembly; sealing a chamber defined within the connecting flange assembly from ambient water with the connecting flange assembly; disengaging the connecting flange assembly from the frame with the hydraulic actuator; and extracting fluid through the connecting flange assembly and the hole drilled by the fluid drill.

[0196] Example 18 - The method of Example 17, wherein disengaging the flange connecting assembly from the frame with the hydraulic actuator includes rotating a locking ring from a locked position to an unlocked position such that the frame can be separated from the flange connecting assembly when the locking ring is moved to the unlocked position.

[0197] Example 19 - The method of Example 17 or 18, wherein the locking ring includes a plurality of radially extending locking lugs extending inwardly therefrom, and wherein disengaging the flange connecting assembly from the frame with the hydraulic actuator includes rotating the radially extending locking lugs into alignment with corresponding lug slots defined in the flange connecting assembly.

[0198] The method of Example 20 - the method of Example 17, 18, or 19, further comprising, after rotating the radial locking lug to align with the corresponding lug groove, vertically lifting the frame from the flange connection assembly such that the radial locking lug passes through the corresponding lug groove.

[0199] Example Group 4:

[0200] Example 1 - A method for flushing a drill cavity within an underwater drilling system, wherein the underwater drilling system includes a connection flange assembly configured to be attached to a hull, wherein the connection flange assembly includes an upper coupling portion, a lower coupling portion, and a knife gate, and wherein the method includes: placing the underwater drilling system against the hull; securing the underwater drilling system to the hull; drilling self - tapping studs into the hull to secure the connection flange assembly to the hull; pressurizing the drill cavity to test a first seal between the connection flange assembly and the hull; advancing a main drill rod toward the hull to drill a main hole in the hull; retracting the main drill rod through the hull; closing the knife gate of the connection flange assembly to provide a second seal between the upper coupling portion and the lower coupling portion; and discharging the fluid in the drill cavity into a waste bin.

[0201] Example 2 - The method of Example 1, further comprising disengaging the upper coupling portion from the lower coupling portion.

[0202] Example 3 - The method of Example 1 or 2, further comprising actuating the main drill rod during the discharge of the fluid in the drill cavity to agitate the fluid within the upper coupling portion.

[0203] Example 4 - The method of Example 1, 2, or 3, wherein pressurizing the drill cavity includes advancing the main drill rod into the drill cavity.

[0204] Example 5 - An underwater drilling system, comprising: a frame including an upper coupler; a connection flange to be attached to a hull, wherein the connection flange includes a lower coupler, and the lower coupler includes a knife gate actuable to provide a seal between the lower coupler and the upper coupler, wherein the upper coupler is separable from the lower coupler; and a drill cavity including an upper drill cavity defined in the upper coupler and a lower drill cavity defined in the lower coupler. The underwater drilling system further includes a waste bin fluidly connected to the drill cavity through the upper coupler and a pump configured to discharge the fluid in the upper drill cavity into the waste bin.

[0205] Example 6 - The underwater drilling system of Example 5, wherein the pump is configured to pump water into the upper drill cavity to discharge the fluid in the upper drill cavity.

[0206] Example 7 - The underwater drilling system of Example 5 or 6, wherein the waste bin includes a check valve configured to prevent the waste liquid contained in the waste bin from flowing into the upper drill cavity.

[0207] The underwater drilling system of Example 8 - Example 5, 6, or 7 further includes an air discharge valve positioned between the upper drill chamber and the waste box.

[0208] The underwater drilling system of Example 9 - Example 5, 6, 7, or 8, wherein the waste box includes a transparent housing.

[0209] The underwater drilling system of Example 10 - Example 5, 6, 7, 8, or 9, wherein the upper drill chamber includes a first volume, and wherein the waste box includes a second volume greater than the first volume.

[0210] The underwater drilling system of Example 11 - Example 5, 6, 7, 8, 9, or 10, wherein the second volume is at least three times the first volume.

[0211] Example 12 - An underwater drilling system, comprising: a frame including a base; a connecting flange pre - attached to the base, wherein the connecting flange includes a female coupler, a chamber defined in the connecting flange, and a gate, wherein the chamber includes an upper chamber and a lower chamber, the gate being actuable to provide a seal between the upper chamber and the lower chamber, wherein the frame is separable from the female coupler; a container in fluid communication with the upper chamber; and a pump for discharging the fluid in the upper chamber into the container.

[0212] The underwater drilling system of Example 13 - Example 12, wherein the pump is for pumping water into the upper chamber to purge the fluid in the upper chamber.

[0213] The underwater drilling system of Example 14 - Example 12 or 13, wherein the container includes a check valve to prevent the waste fluid contained in the container from flowing into the upper chamber.

[0214] The underwater drilling system of Example 15 - Example 12, 13, or 14 further includes an air purge valve positioned between the upper chamber and the container.

[0215] The underwater drilling system of Example 16 - Example 12, 13, 14, or 15, wherein the container includes a transparent housing.

[0216] The underwater drilling system of Example 17 - Example 12, 13, 14, 15, or 16, wherein the upper chamber includes a first volume, and wherein the container includes a second volume, the second volume being greater than the first volume.

[0217] The underwater drilling system of Example 18 - Example 12, 13, 14, 15, 16, or 17, wherein the second volume is at least three times the first volume.

[0218] Example Group 5:

[0219] Example 1 - An underwater drilling system includes a drilling assembly, a frame supporting the drilling assembly, and a connection flange assembly configured to be attached to a hull by the drilling assembly. The connection flange assembly includes a drill cavity defined therein and an automatic exhaust valve assembly in fluid communication with the drill cavity. The automatic exhaust valve assembly is attached to the frame by a fluid pivot coupling, and the automatic exhaust valve assembly includes an automatic exhaust valve and an external float member.

[0220] Example 2 - The underwater drilling system of Example 1, wherein the fluid pivot joint includes a hydraulic swivel elbow.

[0221] Example 3 - The underwater drilling system of Example 1 or 2, wherein the automatic exhaust valve assembly further includes a body portion defining an internal fluid chamber and an air release orifice, and an internal shuttle valve body including an internal float. The internal float is configured to allow the internal shuttle valve body to move relative to the body portion to seal and unseal the air release orifice.

[0222] Example 4 - The underwater drilling system of Example 1, 2, or 3, wherein the internal shuttle valve body includes an internal tube and an upper vent head. The internal tube includes an open bottom in fluid communication with the internal fluid chamber.

[0223] Example 5 - The underwater drilling system of Example 1, 2, 3, or 4, wherein the upper vent head includes a plug configured to seal and unseal the air release orifice.

[0224] Example 6 - The underwater drilling system of Example 1, 2, 3, 4, or 5, wherein the air release orifice is defined in a top plate of the body portion.

[0225] Example 7 - The underwater drilling system of Example 1, 2, 3, 4, 5, or 6 further includes a waste box in fluid communication with the drill cavity, and the automatic exhaust valve assembly is located upstream of the waste box such that air is configured to be released through the automatic exhaust valve assembly before reaching the waste box.

[0226] Example 8 - An exhaust assembly for use with an underwater drilling system. The exhaust assembly includes an input tube in fluid communication with a drill cavity and a head assembly. The head assembly includes: a frame including an upper vent; a first float; an internal chamber in fluid communication with the input tube and the upper vent; and a shuttle movable within the internal chamber such that air pressure is configured to push the shuttle away from the upper vent to automatically unseal and escape through the upper vent.

[0227] Example 9 - The exhaust assembly of Example 8, wherein the input pipe further includes a tube, and the tube includes a fluid pivot coupling configured to allow the first float to bias the head assembly toward the balanced pressure position.

[0228] Example 10 - The exhaust assembly of Example 8 or 9, wherein the frame includes a chamber wall that defines the internal chamber, and the internal chamber extends between the lower plate and the upper plate of the frame.

[0229] Example 11 - The exhaust assembly of Example 8, 9, or 10, wherein the shuttle includes a second float that engages the chamber wall, and wherein the second float provides an external seal between the upper portion and the lower portion of the internal chamber.

[0230] Example 12 - The exhaust assembly of Example 8, 9, 10, or 11, wherein the upper vent includes a first upper vent, and wherein the shuttle includes an internal tube that includes a second upper vent in fluid communication with the upper portion of the internal chamber and an open bottom in fluid communication with the lower portion of the internal chamber.

[0231] Example 13 - The exhaust assembly of Example 8, 9, 10, 11, or 12, wherein the upper plate includes a first upper plate, and wherein the shuttle further includes a second upper plate configured to seal the first upper vent when the shuttle is in the uppermost position and to unseal the first upper vent when the shuttle is not in the uppermost position.

[0232] Example 14 - The exhaust assembly of Example 8, 9, 10, 11, 12, or 13, wherein a gap is defined between the second float and the first upper plate when the shuttle is in the uppermost position.

[0233] Example 15 - A method for automatically exhausting air from a drill cavity of a subsea drilling assembly, wherein the subsea drilling assembly includes a frame, a drilling assembly mounted to the frame, and a flange assembly, and wherein a drill cavity is defined in the flange assembly, and the method includes attaching the subsea drilling assembly to the hull; drilling through the hull through the flange assembly by the drilling assembly; exhausting air from the drill cavity through an automatic exhaust valve assembly that includes an external float, an internal chamber, and a shuttle that is movable within the internal chamber to seal and unseal a top plate of the automatic exhaust valve assembly when an air pressure is generated that is greater than the fluid pressure applied to the shuttle within the internal chamber; and sealing the flange assembly.

[0234] Example 16 - The method of Example 15, wherein exhausting air from the drill cavity further includes passing air through an internal tube of the shuttle.

[0235] While several forms have been illustrated and described, the applicant does not intend to limit the scope of the appended claims to these details. Many modifications, variations, alterations, substitutions, combinations, and equivalents of these forms can be made without departing from the scope of the present disclosure, and such modifications, variations, and alterations will occur to those skilled in the art. Additionally, the structure of each element associated with the described forms can alternatively be described as a means for providing the function performed by that element. Further, where the materials of certain components are disclosed, other materials can be used. Accordingly, it should be understood that the foregoing description and the appended claims are intended to cover all such modifications, combinations, and variations that fall within the scope of the disclosed forms. The appended claims are intended to cover all such modifications, variations, changes, substitutions, alterations, and equivalents.

[0236] The foregoing detailed description has set forth various forms of devices and / or processes by use of block diagrams, flowcharts, and / or examples. As long as these block diagrams, flowcharts, and / or examples contain one or more functions and / or operations, those skilled in the art will understand that each function and / or operation in these block diagrams, flowcharts, and / or examples can be implemented, individually and / or jointly, by a variety of hardware, software, firmware, or nearly any combination thereof. Those skilled in the art will recognize that certain aspects of the forms disclosed herein can be implemented, in whole or in part, equivalently in an integrated circuit, as one or more computer programs running on one or more computers (e.g., as a program running on one or more computer systems), as software running on multiple processors (e.g., multiple programs running on one or more microprocessors), firmware, or nearly any combination thereof, and that designing the circuitry and / or writing the code for the software and / or firmware will be entirely within the skill of those in the art in light of the present disclosure. Additionally, those skilled in the art will understand that the mechanisms of the subject matter described herein can be distributed in a variety of forms as one or more program products, and that the illustrative forms of the subject matter described herein apply regardless of the particular type of signal-bearing medium actually used to carry out the distribution.

[0237] Instructions for programming logic to perform various disclosed aspects can be stored in a memory within the system, such as dynamic random access memory (DRAM), cache, flash memory, or other memory. Additionally, the instructions can be distributed via a network or other computer-readable medium. Thus, a machine-readable medium can include any mechanism for storing or transmitting information in a form readable by a machine (e.g., a computer), but is not limited to floppy disks, optical disks, optical discs, compact disc read-only memory (CD-ROM) and magneto-optical discs, read-only memory (ROM), random access memory (RAM), erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM), magnetic or optical cards, flash memory, or a tangible machine-readable memory for transmitting information over the Internet via electrical, optical, acoustic, or other forms of propagated signals (e.g., carrier waves, infrared signals, digital signals, etc.). Thus, a non-transitory computer-readable medium includes any type of tangible machine-readable medium suitable for storing or transmitting electronic instructions or information in a form readable by a machine (e.g., a computer).

[0238] As used in any aspect herein, the term "control circuit" can refer to, for example, hardwired circuitry, programmable circuitry (e.g., a computer processor, including one or more individual instruction processing cores, processing units, processors, microcontrollers, microcontroller units, controllers, digital signal processors (DSPs), programmable logic devices (PLDs), programmable logic arrays (PLAs), or field programmable gate arrays (FPGAs)), state machine circuitry, firmware storing instructions executed by the programmable circuitry, and any combination thereof. The control circuit can be embodied, collectively or individually, as circuitry forming part of a larger system, e.g., an integrated circuit (IC), an application specific integrated circuit (ASIC), a system on a chip (SoC), a desktop computer, a laptop computer, a tablet computer, a server, a smartphone, etc. Thus, as used herein, "control circuit" includes, but is not limited to, an electrical circuit having at least one discrete circuit, an electrical circuit having at least one integrated circuit, an electrical circuit having at least one application specific integrated circuit, an electrical circuit forming a general computing device configured by a computer program (e.g., a general computer configured by a computer program that at least partially performs the processes and / or devices described herein, or a microprocessor configured by a computer program that at least partially performs the processes and / or devices described herein), an electrical circuit forming a memory device (e.g., in the form of a random access memory), and / or an electrical circuit forming a communication device (e.g., a modem, a communication switch, or an optoelectronic device). Those skilled in the art will recognize that the subject matter described herein can be implemented in analog or digital fashion or some combination thereof.

[0239] As used herein in any context, the term "logic" can refer to an application, software, firmware, and / or circuitry configured to perform any of the operations described above. Software can be embodied as a software package, code, instructions, an instruction set, and / or data recorded on a non-transitory computer-readable storage medium. Firmware can be embodied as code, instructions, or an instruction set, and / or data that is hard-coded (e.g., non-volatile) in a memory device.

[0240] As used herein in any context, the terms "component", "system", "module", etc. can refer to a computer-related entity, whether hardware, a combination of hardware and software, software, or software in execution.

[0241] As used herein in any context, an "algorithm" refers to a consistent sequence of steps that results in a desired outcome, where a "step" refers to an operation on physical quantities and / or logical states, which may or may not necessarily take the form of electrical or magnetic signals that can be stored, transmitted, combined, compared, and otherwise manipulated. Commonly used to refer to these signals are bits, values, elements, symbols, characters, terms, numbers, etc. These similar terms can be associated with appropriate physical quantities and are merely convenient labels applied to these quantities and / or states.

[0242] A network can include a packet-switched network. Communication devices can be able to communicate with each other using a selected packet-switched network communication protocol. An example communication protocol can include an Ethernet communication protocol, which can be able to permit communication using the Transmission Control Protocol / Internet Protocol (TCP / IP). The Ethernet protocol can conform to or be compatible with the Ethernet standard titled "IEEE 802.3 Standard" published by the Institute of Electrical and Electronics Engineers (IEEE) in December 2008, and / or a later version of that standard. Alternatively or additionally, communication devices can be able to communicate with each other using an X.25 communication protocol. The X.25 communication protocol can conform to or be compatible with a standard promulgated by the International Telecommunication Union - Telecommunication Standardization Sector (ITU-T). Alternatively or additionally, communication devices can be able to communicate with each other using a Frame Relay communication protocol. The Frame Relay communication protocol can conform to or be compatible with a standard promulgated by the Consultative Committee for International Telegraph and Telephone (CCITT) and / or the American National Standards Institute (ANSI). Alternatively or additionally, transceivers can be able to communicate with each other using an Asynchronous Transfer Mode (ATM) communication protocol. The ATM communication protocol can conform to or be compatible with the ATM standard titled "ATM-MPLS Network Interconnection 2.0" published by the ATM Forum in August 2001, and / or a later version of that standard. Of course, different and / or later-developed connection-oriented network communication protocols are equally contemplated herein.

[0243] Unless specifically stated otherwise, which will be apparent from the foregoing disclosure, it should be understood that in the foregoing disclosure, discussions using terms such as "processing", "computing", "operating", "determining", "displaying", etc. refer to actions and processes of a computer system, or similar electronic computing devices, which manipulate and transform data represented as physical (electronic) quantities within computer system registers and memories into other data similarly represented as physical quantities within a computer system memory or register or other such information storage, transmission, or display devices.

[0244] One or more components herein may be referred to as "configured to", "configurable to", "operable / operatively", "adapted / adaptable", "capable", "in accordance with", etc. Those skilled in the art will recognize that "configured to" generally can cover active state components and / or inactive state components and / or standby state components, unless the context requires otherwise.

[0245] Those skilled in the art will recognize that, in general, terms used herein, particularly those used in the appended claims (e.g., the body of the appended claims), are generally intended to be "open" terms (e.g., the term "comprising" should be interpreted as "comprising but not limited to", the term "having" should be interpreted as "having at least", the term "including" should be interpreted as "including but not limited to", etc.). Those skilled in the art will further understand that if an intention to introduce a specific number of introduced claim recitations is present, such intention will be expressly recited in the claim, and in the absence of such recitation, no such intention exists. For example, for the sake of understanding, the following appended claims may contain the use of introductory phrases "at least one" and "one or more" to introduce claim recitations. However, the use of such phrases should not be construed as implying that introducing a claim recitation by the indefinite article "a" or "an" will limit the claim recitation containing such introduction to a claim having only one such recitation, even if the same claim includes the introductory phrase "one or more" or "at least one" and the indefinite article such as "a" or "an" (e.g., "a" and / or "an" should generally be interpreted as meaning "at least one" or "one or more"); the same holds for the use of the definite article to introduce a claim recitation.

[0246] In addition, even if the specific number of claim statements introduced is explicitly recited, those skilled in the art will recognize that such a recitation should generally be interpreted to mean at least the recited number (e.g., a simple recitation of "two statements" without additional modifiers generally means at least two statements, or two or more statements). Further, in cases where a convention similar to "at least one of A, B, and C, etc." is used, typically such a construction is intended to have the meaning of the convention as understood by those skilled in the art (e.g., a "system having at least A, B, and C" will include, but not be limited to, systems having A alone, B alone, C alone, A and B together, A and C together, B and C together, and / or A, B, and C together, etc.). In cases where a convention similar to "at least one of A, B, or C, etc." is used, typically such a construction is intended to have the meaning of the convention as understood by those skilled in the art (e.g., a "system having at least A, B, or C" will include, but not be limited to, systems having A alone, B alone, C alone, A and B together, A and C together, B and C together, and / or A, B, and C together, etc.). Those skilled in the art will further understand that, generally, disjunctive words and / or phrases representing two or more alternatives, whether in the specification, claims, or drawings, should be understood to contemplate including one of the terms, any one of the terms, or both terms, unless the context dictates otherwise. For example, the phrase "A or B" will generally be understood to include the possibilities of "A" or "B" or "A and B".

[0247] Regarding the appended claims, those skilled in the art will appreciate that the operations recited therein can be performed in any order. Further, although various operation flowcharts are presented in sequence, it should be understood that the various operations can be performed in an order different from that shown, or can be performed in parallel. Examples of such alternative orderings can include overlapping, interleaving, interrupting, reordering, incrementing, preparatory, supplementary, simultaneous, reverse, or other variant orderings, unless the context dictates otherwise. Additionally, terms such as "responsive to", "associated with", or other past tense adjectives generally are not intended to exclude such variants, unless the context dictates otherwise.

[0248] It should be noted that any reference to "an aspect", "one aspect", "an example", "one example", etc. means that the specific feature, structure, or characteristic described in association with that aspect is included in at least one aspect. Thus, the phrases "in one aspect", "in one aspect", "in one example", and "in one example" that appear throughout the specification do not necessarily all refer to the same aspect. Further, the specific features, structures, or characteristics can be combined in any suitable manner in one or more aspects.

[0249] Any patent application, patent, non-patent publication, or other publicly available material mentioned in this specification and / or in any application data sheet is hereby incorporated by reference to the extent that the incorporated material is not inconsistent with this disclosure. Thus, and to the extent necessary, the disclosure set forth herein supersedes any conflicting material incorporated by reference herein. Any material or portion thereof that is intended to be incorporated by reference but conflicts with the existing definitions, statements, or other publicly available material set forth herein will be incorporated only to the extent that no conflict arises between the incorporated material and the existing publicly available material.

[0250] In summary, numerous benefits resulting from the adoption of the concepts described herein have been described. The foregoing description of one or more forms has been presented for purposes of illustration and description. It is not exhaustive and is not limited to the precise forms disclosed. Modifications or variations are possible in light of the above teachings. One or more forms have been selected and described in order to illustrate the principles and practical applications so that those of ordinary skill in the art can make and use various forms and various modifications suitable for the intended use. The claims submitted are intended to define the general scope.

Claims

1. An underwater drilling assembly, comprising: A drilling assembly; A connecting flange assembly configured to be attached to the hull by the drilling assembly, wherein the connecting flange assembly includes an upper flange and a female coupling portion; And A frame supporting the drilling assembly, wherein the frame includes: A lower platform; Attachment legs extending from the lower platform and configured to attach the underwater drilling assembly to the hull; A male coupling portion attached to the lower platform, wherein the male coupling portion is configured to be received by the female coupling portion, and wherein the male coupling portion includes a lower flange; and A locking assembly attached to the frame, wherein the locking assembly is configured to lock and unlock the upper flange and the lower flange to couple and disassemble the male coupling portion and the female coupling portion.

2. The underwater drilling assembly according to claim 1, wherein the locking assembly includes a locking ring configured to rotate to couple and disassemble the upper flange and the lower flange.

3. The underwater drilling assembly according to claim 2, wherein the locking ring includes a plurality of radially locking lugs, wherein the lower flange includes a plurality of slots configured to receive the radially locking lugs, and wherein the locking ring is rotatable relative to the upper flange to axially lock the male coupling portion and the connecting flange assembly.

4. The underwater drilling assembly according to claim 2, wherein the locking assembly further includes a hydraulic actuator configured to rotate the locking ring relative to the frame, the male coupling portion, and the connecting flange assembly.

5. The underwater drilling assembly according to claim 1, wherein the male coupling portion includes a sealing ring configured to fluidly seal the male coupling portion and the female coupling portion.

6. The underwater drilling assembly according to claim 1, wherein the connecting flange assembly further includes guide posts extending therefrom, configured to engage the attachment legs to prevent relative rotation between the connecting flange assembly and the lower platform.

7. The underwater drilling assembly according to claim 1, wherein the male coupling portion includes a machined outer surface and the female coupling portion includes a machined inner surface configured to mate with the machined outer surface.

8. The underwater drilling assembly according to claim 1, wherein the male coupling portion includes a chamfered tube edge receivable within the female coupling portion.

9. An assembly, comprising: A frame defining a first hole; A connecting flange defining a second hole, wherein an axis passes through the first hole and the second hole, and wherein a drill bit is movable along the axis; and A locking device mounted to the frame, wherein the locking device is rotatable about the axis between a locked position and an unlocked position, at the locked position the connecting flange is fixed to the frame, and at the unlocked position the connecting flange is disengaged from the frame such that the frame can be pulled away from the connecting flange when the connecting flange is fastened to the hull.

10. The assembly according to claim 9, wherein the locking device includes a locking ring configured to rotate to couple and disassemble the connecting flange and the frame.

11. The assembly according to claim 10, wherein the locking ring includes a plurality of radially extending locking lugs, wherein the connecting flange includes a plurality of slots configured to receive the radially locking lugs, and wherein the locking ring is rotatable relative to the frame and the connecting flange to axially lock the frame and the connecting flange together.

12. The assembly according to claim 10 further includes a hydraulic actuator configured to rotate the locking ring relative to the frame and the connecting flange.

13. The assembly according to claim 9, wherein the frame includes a male coupler that includes a seal configured to fluidly seal the frame and the connecting flange.

14. The assembly according to claim 9, wherein the frame includes a plurality of legs, and wherein the connecting flange further includes guide posts extending therefrom configured to engage the plurality of legs to prevent relative rotation between the connecting flange and the frame.

15. The assembly according to claim 9, wherein the frame includes a male coupler that includes a machined outer surface, and wherein the connecting flange includes a female coupler that includes a machined inner surface configured to mate with the machined outer surface.

16. The assembly according to claim 15, wherein the male coupler includes a chamfered tube edge receivable within the female coupler.

17. A method for extracting fluid from a sunken ship using an underwater drilling assembly, the underwater drilling assembly including a frame, a drilling assembly attached to the frame, and a connecting flange assembly, the method comprising: attaching the connecting flange assembly to the frame with a hydraulic actuator; lowering the underwater drilling assembly to the exterior of the sunken ship; actuating a leg assembly of the underwater drilling assembly to hold the frame of the underwater drilling assembly to the exterior; drilling at least one self-tapping stud through the connecting flange assembly and into the exterior with a fluid drill of the underwater drilling assembly to secure the connecting flange assembly to the exterior; drilling into the sunken ship with a fluid drill within an internal void defined in the connecting flange assembly; sealing a chamber defined within the connecting flange assembly from ambient water with the connecting flange assembly; disengaging the connecting flange assembly from the frame with a hydraulic actuator; and extracting fluid through the connecting flange assembly and the hole drilled by the fluid drill.

18. The method according to claim 17, wherein disengaging the flange connection assembly from the frame with a hydraulic actuator includes rotating a locking ring from a locked position to an unlocked position such that the frame can be separated from the flange connection assembly when the locking ring is moved to the unlocked position.

19. The method according to claim 18, wherein the locking ring includes a plurality of radially extending locking lugs extending inwardly therefrom, and wherein disengaging the flange connection assembly from the frame with a hydraulic actuator includes rotating the radially extending locking lugs into alignment with corresponding lug slots defined in the flange connection assembly.

20. The method according to claim 19, further comprising vertically lifting the frame away from the flange connection assembly after rotating the radially extending locking lugs into alignment with the corresponding lug slots such that the radially extending locking lugs pass through the corresponding lug slots.

Images