SUBSEA MECHANICAL DISPERSION SYSTEM

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to U.S. Provisional Patent Application Ser. No. 63/565,525 titled “Subsea Mechanical Dispersion System” and filed on Mar. 14, 2024, the entire contents of which are hereby incorporated herein by reference.

TECHNICAL FIELD

The present disclosure relates generally to subsea field operations, and more particularly to systems, methods, and devices for subsea mechanical dispersion systems used in blowouts.

BACKGROUND

Subsea field operations designed to extract subterranean resources (e.g., oil, natural gas) are subject to extreme conditions, such as high pressures and temperatures. On occasion, an event known as a blowout occurs, where there is a loss of control of the subsea well. As a result, oil effluent is released into the water from the subterranean formation, and this effluent typically forms a plume as it rises to the waterline and accumulates at the surface. Dispersing the oil within the plume before the oil reaches the surface is desirable to reduce the concentration of volatile organic compounds which pose health and safety risks to mariners and responders working at the waterline in response to the blowout. Dispersion, additionally, is known to mitigate the overall impact of releasing subterranean effluent into the seawater column by helping to suspend the effluent in droplet form.

SUMMARY

In general, in one aspect, the disclosure relates to a subsea mechanical dispersion system, which can include a dispersion device comprising a base, a securing mechanism, and a bail, where the base has an inlet and a base wall forming a base cavity that provides a continuous path from the inlet to the bail, where the securing mechanism is coupled to the base wall, where the securing mechanism, when in an engaged position, is configured to affix the base to an outer surface of a mandrel at a top end of a remainder of a subterranean string, where the bail comprises a bail wall that forms a channel, and where the channel is continuous from the base cavity at its proximal end and a nozzle at its distal end. The subsea mechanical dispersion system can also include a subsea injection pump that is configured to pump a fluid while located in water. The subsea mechanical dispersion system can further include piping positioned between and coupled to the subsea injection pump and the inlet of the base, where the subsea injection pump, when operating, is configured to pump the fluid through the piping, the base cavity, and the channel in the bail to the nozzle.

In another aspect, the disclosure relates to a dispersion device of a subsea mechanical dispersion system. The subsea mechanical dispersion system can include a base having an inlet and a base wall forming a base cavity, where the inlet is configured to couple to piping that provides a fluid, propelled by a subsea pump, to the base cavity. The subsea mechanical dispersion system can also include a securing mechanism coupled to the base wall, where the securing mechanism, when in an engaged position, is configured to affix the base to an outer surface of a mandrel at a top end of a remainder of a subterranean string. The subsea mechanical dispersion system can further include a bail comprising a bail wall that forms a channel, where the channel is continuous with the base cavity through a nozzle at its distal end, and where the channel and the base cavity provide a continuous path from the inlet to the nozzle.

These and other aspects, objects, features, and embodiments will be apparent from the following description and the appended claims.

BRIEF DESCRIPTION OF THE DRAWINGS

The drawings illustrate only example embodiments and are therefore not to be considered limiting in scope, as the example embodiments may admit to other equally effective embodiments. The elements and features shown in the drawings are not necessarily to scale, emphasis instead being placed upon clearly illustrating the principles of the example embodiments. Additionally, certain dimensions or positions may be exaggerated to help visually convey such principles. In the drawings, the same reference numerals used in different figures may designate like or corresponding but not necessarily identical elements.

FIG. 1 shows a block diagram of a subsea mechanical dispersion system according to certain example embodiments.

FIGS. 2A and 2B show an example of a bail of an example subsea mechanical dispersion system according to certain example embodiments.

FIGS. 3A and 3B show another example of a bail of an example subsea mechanical dispersion system according to certain example embodiments.

FIGS. 4 through 6 show other examples of a bail of example subsea mechanical dispersion systems according to certain example embodiments.

FIGS. 7A and 7B show an example of a dispersion device according to certain example embodiments.

FIGS. 8 and 9 show a top view of other examples of dispersion devices according to certain example embodiments.

FIGS. 10A and 10B show another example of part of a system that includes a subsea mechanical dispersion system according to certain example embodiments.

FIG. 11 shows another example of part of a system that includes a dispersion device according to certain example embodiments.

FIGS. 12 through 15 show an example of a system that implements a subsea mechanical dispersion system in the field according to certain example embodiments.

DETAILED DESCRIPTION

In general, example embodiments provide systems, methods, and devices for subsea mechanical dispersion systems. Example embodiments can provide a number of benefits. Such benefits can include, but are not limited to, rapid installation, case of installation, effective dispersion of oil at the source of a blowout, configurability, compatible with implementation by remotely operated vehicle (ROV), and compliance with industry standards that apply to subsea field operations. While example embodiments described herein are directed for use in subsea field operations directed to oil production, in alternative embodiments, example subsea mechanical dispersion systems may be used additionally or alternatively with other types of applications in which subsea dispersion is desired.

As defined herein, a user may be any person that interacts with subsea equipment and/or subsea field operations. Examples of a user may include, but are not limited to, a drilling engineer, a production engineer, a field engineer, a roughneck, a company representative, a mechanic, an operator, an employee, a consultant, a contractor, an ROV, and a manufacturer's representative. Example subsea mechanical dispersion systems (or portions thereof) can be made of one or more of a number of suitable materials to allow the subsea mechanical dispersion systems (or portions thereof) to meet certain standards and/or regulations while also maintaining durability in light of the one or more conditions under which the subsea mechanical dispersion systems, including components or portions thereof, may be exposed. Examples of such materials can include, but are not limited to, aluminum, stainless steel, fiberglass, glass, plastic (e.g., polytetrafluoroethylene (PTFE), nylon), ceramic, and rubber.

Example subsea mechanical dispersion systems, or portions or components thereof, described herein can be made from a single piece (e.g., from a mold, using injection molding, using a die cast process, using a milling and/or lathing process, using an extrusion process, 3D printing, combinations thereof). In addition, or in the alternative, example subsea mechanical dispersion systems (including portions or components thereof) can be made from multiple pieces that are mechanically coupled to each other. In such a case, the multiple pieces can be mechanically coupled to each other using one or more of a number of coupling methods, including but not limited to epoxy, welding, fastening devices, compression fittings, mating threads, snap fittings, flanges with gaskets, and slotted fittings. One or more pieces that are mechanically coupled to each other can be coupled to each other in one or more of a number of ways, including but not limited to fixedly, hingedly, removably, slidably, rotatably, and threadably.

Components and/or features described herein can include elements that are described as coupling, fastening, securing, abutting against, in communication with, or other similar terms. Such terms are merely meant to distinguish various elements and/or features within a component or device and are not meant to limit the capability or function of that particular element and/or feature. For example, a feature described as a “coupling feature” can couple, secure, fasten, abut against, and/or perform other functions aside from merely coupling.

A coupling feature (including a complementary coupling feature) as described herein can allow one or more components and/or portions of an example subsea mechanical dispersion system to become coupled, directly or indirectly, to one or more other components of the subsea mechanical dispersion system and/or an external component (e.g., an electrical cable, an ROV). A coupling feature can include, but is not limited to, a clamp, a portion of a hinge, a channel, an aperture, a recessed area, a protrusion, a hole or other type of aperture, a slot, a tab, a detent, and mating threads. One portion of an example subsea mechanical dispersion system can be coupled to another component or feature of the subsea mechanical dispersion system and/or to an external component by the direct use of one or more coupling features.

In addition, or in the alternative, a portion of an example subsea mechanical dispersion system can be coupled to another component or feature of the subsea mechanical dispersion system and/or to an external component using one or more independent devices that interact with one or more coupling features disposed on a component or feature of the subsea mechanical dispersion system. Examples of such devices can include, but are not limited to, a pin, a hinge, a fastening device (e.g., a bolt, a screw, a rivet), epoxy, glue, adhesive, and a spring. One coupling feature described herein can be the same as, or different than, one or more other coupling features described herein. A complementary coupling feature as described herein can be a coupling feature that mechanically couples, directly or indirectly, with another coupling feature.

The use of the terms “substantially”, “about”, “approximately”, and similar terms applies to all numeric values, whether or not explicitly indicated. These terms generally refer to a range of numbers that one of ordinary skill in the art would consider as a reasonable amount of deviation to the recited numeric values (i.e., having the equivalent function or result). For example, this term may be construed as including a deviation of +10 percent of the given numeric value provided such a deviation does not alter the end function or result of the value. Therefore, an angle that is substantially perpendicular may be construed to be within a range from 81° to 99°. Furthermore, a range may be construed to include the start and the end of the range. For example, a range of 10% to 20% (i.e., range of 10%-20%) includes 10% and also includes 20%, and includes percentages in between 10% and 20%, unless explicitly stated otherwise herein. Similarly, a range of between 10% and 20% (i.e., range between 10%-20%) includes 10% and also includes 20%, and includes percentages in between 10% and 20%, unless explicitly stated otherwise herein.

A “subterranean formation” refers to practically any volume under a surface. For example, it may be practically any volume under a terrestrial surface (e.g., a land surface), practically any volume under a seafloor, etc. Each subsurface volume of interest may have a variety of characteristics, such as petrophysical rock properties, reservoir fluid properties, reservoir conditions, hydrocarbon properties, or any combination thereof. For example, each subsurface volume of interest may be associated with one or more of: temperature, porosity, salinity, permeability, water composition, mineralogy, hydrocarbon type, hydrocarbon quantity, reservoir location, pressure, etc. Those of ordinary skill in the art will appreciate that the characteristics are many, including, but not limited to: shale gas, shale oil, tight gas, tight oil, tight carbonate, carbonate, vuggy carbonate, unconventional (e.g., a permeability of less than 25 millidarcy (mD) such as a permeability of from 0.000001 mD to 25 mD)), diatomite, geothermal, mineral, etc. The terms “formation”, “subsurface formation”, “hydrocarbon-bearing formation”, “reservoir”, “subsurface reservoir”, “subsurface area of interest”, “subsurface region of interest”, “subsurface volume of interest”, and the like may be used synonymously. The term “subterranean formation” is not limited to any description or configuration described herein.

A “well” or a “wellbore” refers to a single hole, usually cylindrical, that is drilled into a subsurface volume of interest. A well or a wellbore may be drilled in one or more directions. For example, a well or a wellbore may include a vertical well, a horizontal well, a deviated well, and/or other type of well. A well or a wellbore may be drilled in the subterranean formation for exploration and/or recovery of resources. A plurality of wells (e.g., tens to hundreds of wells) or a plurality of wellbores are often used in a field depending on the desired outcome. For subsea operations, a well may also include a riser in the water, where the riser helps protect and/or isolate the wellbore environment from the water that surrounds it.

A well or a wellbore may be drilled into a subsurface volume of interest using practically any drilling technique and equipment known in the art, such as geosteering, directional drilling, etc. Drilling the well may include using a tool, such as a drilling tool that includes a drill bit and a drill string. Drilling fluid, such as drilling mud, may be used while drilling in order to cool the drill tool and remove cuttings. Other tools may also be used while drilling or after drilling, such as measurement-while-drilling (MWD) tools, seismic-while-drilling tools, wireline tools, logging-while-drilling (LWD) tools, or other downhole tools. After drilling to a predetermined depth, the drill string and the drill bit may be removed, and then the casing, the tubing, and/or other equipment may be installed according to the design of the well. The equipment to be used in drilling the well may be dependent on the design of the well, the subterranean formation, the hydrocarbons, and/or other factors.

A well may include a plurality of components, such as, but not limited to, a casing, a liner, a tubing string, a sensor, a packer, a screen, a gravel pack, artificial lift equipment (e.g., an electric submersible pump (ESP)), and/or other components. If a well is drilled offshore, the well may include one or more of the previous components plus other offshore components, such as a riser. A well may also include equipment to control fluid flow into the well, control fluid flow out of the well, or any combination thereof. For example, a well may include a wellhead, a choke, a valve, a blowout preventer (BOP), and/or other control devices. These control devices may be located on the surface (e.g., on the seabed), in the subsurface (e.g., downhole in the well), or any combination thereof. In some embodiments, the same control devices may be used to control fluid flow into and out of the well. In some embodiments, different control devices may be used to control fluid flow into and out of a well. In some embodiments, the rate of flow of fluids through the well may depend on the fluid handling capacities of the surface facility that is in fluidic communication with the well. The equipment to be used in controlling fluid flow into and out of a well may be dependent on the well, the subsurface region, the surface facility, and/or other factors. Moreover, sand control equipment and/or sand monitoring equipment may also be installed (e.g., downhole and/or on the surface). A well can on occasion use wireline services for wellbore evaluation (“logging”), equipment retrieval (“fishing”), conveyance of downhole tools, and the like. A well may also include any completion hardware that is not discussed separately. The term “well” may be used synonymously with the terms “borehole,” “wellbore,” or “well bore.” The term “well” is not limited to any description or configuration described herein.

It is understood that when combinations, subsets, groups, etc. of elements are disclosed (e.g., combinations of components in a composition, or combinations of steps in a method), that while specific reference of each of the various individual and collective combinations and permutations of these elements may not be explicitly disclosed, each is specifically contemplated and described herein. By way of example, if an item is described herein as including a component of type A, a component of type B, a component of type C, or any combination thereof, it is understood that this phrase describes all of the various individual and collective combinations and permutations of these components. For example, in some embodiments, the item described by this phrase could include only a component of type A.

In some embodiments, the item described by this phrase could include only a component of type B. In some embodiments, the item described by this phrase could include only a component of type C. In some embodiments, the item described by this phrase could include a component of type A and a component of type B. In some embodiments, the item described by this phrase could include a component of type A and a component of type C. In some embodiments, the item described by this phrase could include a component of type B and a component of type C. In some embodiments, the item described by this phrase could include a component of type A, a component of type B, and a component of type C. In some embodiments, the item described by this phrase could include two or more components of type A (e.g., A1 and A2).

In some embodiments, the item described by this phrase could include two or more components of type B (e.g., B1 and B2). In some embodiments, the item described by this phrase could include two or more components of type C (e.g., C1 and C2). In some embodiments, the item described by this phrase could include two or more of a first component (e.g., two or more components of type A (A1 and A2)), optionally one or more of a second component (e.g., optionally one or more components of type B), and optionally one or more of a third component (e.g., optionally one or more components of type C).

In some embodiments, the item described by this phrase could include two or more of a first component (e.g., two or more components of type B (B1 and B2)), optionally one or more of a second component (e.g., optionally one or more components of type A), and optionally one or more of a third component (e.g., optionally one or more components of type C). In some embodiments, the item described by this phrase could include two or more of a first component (e.g., two or more components of type C (C1 and C2)), optionally one or more of a second component (e.g., optionally one or more components of type A), and optionally one or more of a third component (e.g., optionally one or more components of type B).

In the foregoing figures showing example embodiments of subsea mechanical dispersion systems, one or more of the components shown may be omitted, repeated, and/or substituted. Accordingly, example embodiments of subsea mechanical dispersion systems should not be considered limited to the specific arrangements of components shown in any of the figures. For example, features shown in one or more figures or described with respect to one embodiment can be applied to another embodiment associated with a different figure or description.

In certain example embodiments, subsea field operations that include the use of subsea mechanical dispersion systems may be subject to meeting certain standards and/or requirements. Examples of entities that set such standards and/or requirements can include, but are not limited to, the Society of Petroleum Engineers, the American Petroleum Institute (API), the International Standards Organization (ISO), Bureau of Safety and Environmental Enforcement (BSEE), and the Occupational Safety and Health Administration (OSHA). Use of example embodiments described herein meet (and/or allow the subsea field operations to meet) such standards and/or requirements when applicable.

If a component of a figure is described but not expressly shown or labeled in that figure, the label used for a corresponding component in another figure can be inferred to that component. Conversely, if a component in a figure is labeled but not described with respect to that figure, the description for such component can be substantially the same as the description for a corresponding component in another figure. The numbering scheme for the various components in the figures herein is such that each component is a three-digit number or a four-digit number, and corresponding components in other figures have the identical last two digits.

In addition, a statement that a particular embodiment (e.g., as shown in a figure herein) does not have a particular feature or component does not mean, unless expressly stated, that such embodiment is not capable of having such feature or component. For example, for purposes of present or future claims herein, a feature or component that is described as not being included in an example embodiment shown in one or more particular drawings is capable of being included in one or more claims that correspond to such one or more particular drawings herein.

Example embodiments of subsea mechanical dispersion systems will be described more fully hereinafter with reference to the accompanying drawings, in which example embodiments of subsea mechanical dispersion systems are shown. Subsea mechanical dispersion systems may, however, be embodied in many different forms and should not be construed as limited to the example embodiments set forth herein. Rather, these example embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of subsea mechanical dispersion systems to those of ordinary skill in the art. Like, but not necessarily the same, elements (also sometimes called components) in the various figures are denoted by like reference numerals for consistency.

Terms such as “first”, “second”, “above”, “below”, “inner”, “outer”, “distal”, “proximal”, “end”, “top”, “bottom”, “upper”, “lower”, “side”, “left”, “right”, “front”, “rear”, and “within”, when present, are used merely to distinguish one component (or part of a component or state of a component) from another. Such terms are not meant to denote a preference or a particular orientation. Such terms are not meant to limit embodiments of subsea mechanical dispersion systems. In the following detailed description of the example embodiments, numerous specific details are set forth in order to provide a more thorough understanding of the invention. However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details. In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description.

FIG. 1 shows a block diagram of an example subsea mechanical dispersion system 100 according to certain example embodiments. The subsea mechanical dispersion system 100 of FIG. 1 includes a dispersion device 110, a subsea injection pump 140, one or more optional secondary subsea injection pumps 145, one or more optional storage containers 150, one or more optional energy storage devices 195, piping 148, one or more valves 185, an optional power source 196, and an optional electrical cable 197. The dispersion device 110 of the subsea mechanical dispersion system 100 may include a base 120, a securing mechanism 130, and one or more bails 180.

The piping 148 of the subsea mechanical dispersion system 100 may include multiple pipes, ducts, elbows, joints, sleeves, collars, and similar components that are coupled to each other (e.g., using coupling features such as mating threads) to establish a network for transporting fluids (e.g., fluid 141, fluid 146, fluid 111) within the subsea mechanical dispersion system 100. Each component of the piping 148 may have an appropriate size (e.g., inner diameter, outer diameter) and be made of an appropriate material (e.g., steel, PVC, copper) to safely and efficiently handle the pressure, temperature, flow rate, and other characteristics of the fluids that flow therethrough in a subsea environment. Some or all of the piping 148 may be rigid and/or flexible.

There may be a number of valves 185 placed in-line with the piping 148 (or portions thereof) at various locations in the subsea mechanical dispersion system 100 to control the flow of fluids (e.g., fluid 141, fluid 146, fluid 111) through the piping 148. A valve 185 may have one or more of any of a number of configurations, including but not limited to a check valve, a guillotine valve, a ball valve, a gate valve, a butterfly valve, a pinch valve, a needle valve, a plug valve, a diaphragm valve, and a globe valve. One valve 185 may be configured the same as or differently compared to another valve 185 in the subsea mechanical dispersion system 100. Also, one valve 185 may be controlled (e.g., manually by a ROV) the same as or differently compared to another valve 185 in the subsea mechanical dispersion system 100.

The subsea injection pump 140 of the subsea mechanical dispersion system 100 is configured to pump a fluid 141 (e.g., water) through the piping 148 toward the dispersion device 110. The subsea injection pump 140 is also configured to operate in a subsea environment for an extended period of time (e.g., days, weeks, months, years). In addition to one or more pumps, the subsea injection pump 140 may include one or more of a number of other pieces of equipment to operate. Examples of such other pieces of equipment may include, but are not limited to, a motor, an electrical cable, a relay, a controller, a filter, a contactor, a compressor, a switch, a meter, an inverter, a converter, a transformer, and a sensor device.

In certain example embodiments, the fluid 141 pumped by the subsea injection pump 140 is water from the ambient environment (e.g., subsea) in which the subsea mechanical dispersion system 100 is located. In such cases, a filter of the subsea injection pump 140 may be used to filter out sediment and other debris located near the seabed. In addition, or in the alternative, the fluid 141 pumped by the subsea injection pump 140 may include one or more fluids that are not part of the ambient environment. In such cases, one of the optional storage containers 150, discussed below, may provide the fluid 141 (or portions thereof) to the subsea injection pump 140.

Operation of the subsea injection pump 140 may be enabled by power provided by one or more of a number of sources. For example, a power source 196 (e.g., a diesel generator, an array of solar panels) located separately from the subsea mechanical dispersion system 100 (e.g., located on a platform above the waterline) may provide power to the subsea injection pump 140 through an electrical cable 197. As another example, in addition or in the alternative, the subsea injection pump 140 may receive power from the optional energy storage device 195 (discussed below).

If there are no secondary subsea injection pumps 145, then the fluid 141 pumped by the subsea injection pump 140 becomes the fluid 111 received by the dispersion device 110. Alternatively, if there are one or more secondary subsea injection pumps 145 in the subsea mechanical dispersion system 100, then the fluid 141 pumped by the subsea injection pump 140 is mixed with one or more other fluids 146 pumped by the secondary subsea injection pumps 145 within the piping 148 (at approximately the junction 149) to become the fluid 111 received by the dispersion device 110.

In some cases, the subsea mechanical dispersion system 100 may include one or more secondary subsea injection pumps 145. In this example, there may be X secondary subsea injection pumps 145 (secondary subsea injection pump 145-1 through secondary subsea injection pump 145-X). Each secondary subsea injection pump 145, when part of the subsea mechanical dispersion system 100, is configured to pump a fluid 146 (e.g., a surfactant, a dispersant) through the piping 148 toward the dispersion device 110. For example, the secondary subsea injection pump 145-1 pumps fluid 146-1 toward the dispersion device 110, and the secondary subsea injection pump 145-X pumps fluid 146-X toward the dispersion device 110.

Each secondary subsea injection pump 145 is also configured to operate in a subsea environment for an extended period of time (e.g., days, weeks, months, years). In addition to one or more pumps, a secondary subsea injection pump 145 may include one or more of a number of other pieces of equipment to operate. Examples of such other pieces of equipment may include, but are not limited to, a motor, an electrical cable, a relay, a controller, a filter, a contactor, a compressor, a switch, a meter, an inverter, a converter, a transformer, and a sensor device. When the subsea mechanical dispersion system 100 includes multiple secondary subsea injection pumps 145, the configuration (e.g., pumping capacity, amperage rating of the pump motor) of one of the secondary subsea injection pumps 145 may be the same as, or different than, the configuration of one or more of the other secondary subsea injection pumps 145.

In certain example embodiments, the fluid 146 pumped by a secondary subsea injection pump 145 is a liquid, solid, and/or gas that is not (or at least does not entirely include) water from the ambient environment (e.g., subsea) in which the subsea mechanical dispersion system 100 is located. Rather, at least some of the fluid 146 pumped by a secondary subsea injection pump 145 through the piping 148 originates from one or more storage containers 150, where each storage container 150 acts as a source of a fluid 146 or a component of one or more of the fluids 146.

Each storage container 150 is configured to be placed in a subsea environment for an extended period of time (e.g., days, weeks, months, years) without allowing the ambient water to enter the storage container 150 and mix with the fluid 146 or component of a fluid 146 located within the storage container 150. A storage container 150 may be or include a tank, a vessel, a container, and/or some other form of storage. In some cases, a storage container 150 may be or include a bladder or similar feature. In such a case, the bladder may allow ingress of ambient water (e.g., seawater) into the storage container 150 without mixing with the contents (e.g., a fluid 146) so as to allow more complete evacuation of the fluid 146 from the storage container 150. When the subsea mechanical dispersion system 100 includes a storage container 150, the contents of the storage container 150 may be provided to one or more of the secondary subsea injection pumps 145 and/or the subsea injection pump 140 through the piping 148.

When the subsea mechanical dispersion system 100 includes a storage container 150, there can be any number of storage containers 150. In this case, there are Y optional storage containers 150 (storage container 150-1 through storage container 150-Y). The number of storage containers 150 in the subsea mechanical dispersion system 100 can be the same as, or different than, the number of secondary subsea injection pumps 145. The contents of one storage container 150 may be fed to one or more different secondary subsea injection pumps 145 and/or to the subsea injection pump 140. When the subsea mechanical dispersion system 100 includes multiple storage containers 150, the configuration (e.g., capacity, shape, size, material) of one of the storage containers 150 may be the same as, or different than, the configuration of one or more of the other storage containers 150.

Operation of a secondary subsea injection pump 145 may be enabled by power provided by one or more of a number of sources. For example, a power source 196 (e.g., a diesel generator, an array of solar panels, a generator propelled by tidal power) located separately from (e.g., located on a platform above the waterline) or as part of the subsea mechanical dispersion system 100 may provide power to a secondary subsea injection pump 145 through an electrical cable 197. As another example, in addition or in the alternative, a secondary subsea injection pump 145 may receive power from the optional energy storage device 195 (discussed below).

Each of the optional energy storage devices 195 of the subsea mechanical dispersion system 100 may be configured to provide power that is of a type (e.g., alternating current, direct current) and level (e.g., 12V, 24V, 120V) that may be used by one or more of the secondary subsea injection pumps 145 (or portions thereof), the energy storage device 195, and/or by the subsea injection pump 140 (or portions thereof). Each energy storage device 195 can use one or more of any type of storage technology, including but not limited to a battery (e.g., rechargeable, non-rechargeable), a flywheel, an ultracapacitor, and a supercapacitor.

If the energy storage device 195 includes a battery, the battery may utilize any type of battery technology, including but not limited to lithium ion, nickel-cadmium, lead/acid, solid state, graphite anode, titanium dioxide, nickel cadmium, nickel metal hydride, nickel iron, alkaline, and lithium polymer. In some cases, one or more of the energy storage devices 195 may be able to convert, invert, transform, and/or otherwise manipulate power. There can be any number of energy storage devices 195. In some cases, one or more of the energy storage devices 195 may be used to control the position or state of one or more of the valves 185 in the subsea mechanical dispersion system 100. Each energy storage device 195 may be configured to operate in a subsea environment for an extended period of time (e.g., days, weeks, months, years).

In some cases, as when the energy storage device 195 is configured to receive power from the power source 196 through an electrical cable 197, some or all of the energy storage device 195 may have recharging capabilities. For example, if the energy storage device 195 includes batteries, then some or all of the batteries may be rechargeable using power (in the form of charging power) provided by the power source 196 on some basis (continually, periodically, randomly).

In addition, or in the alternative, if the power source 196 is located in the subsea proximate to the other equipment (e.g., the subsea injection pump 140, one or more of the secondary subsea injection pumps 145), then the energy storage device 195 may be configured to provide, through an electrical cable 197, power (e.g., ancillary power) to the power source 196 to help the power source 196 operate in providing power to one or more components (e.g., the subsea injection pump 140, one or more of the secondary subsea injection pumps 145) of the subsea mechanical dispersion system 100.

The optional power source 196 may provide power via the electrical cable 197 to the subsea injection pump 140, one or more of the secondary subsea injection pumps 145, and/or other components of the subsea mechanical dispersion system 100. The power source 196 can include one or more of a number of components. Examples of such components can include, but are not limited to, an electrical conductor, a coupling feature (e.g., an electrical connector), a transformer, an inductor, a resistor, a capacitor, a diode, a transistor, and a fuse.

The power source 196 can be, or include, for example, an energy storage device (similar to an energy storage device 195), a circuit breaker, and/or an independent source of generation (e.g., a diesel generator, a photovoltaic solar generation system). The power source 196 can also include one or more components (e.g., a switch, a relay, a controller) that allow the power source 196 to communicate with and/or follow instructions from a user, a controller, and/or some other entity or component. The power source 196 provides power that is of a type (e.g., alternating current, direct current) and level (e.g., 12V, 24V, 120V) that may be used by the subsea injection pump 140, one or more of the secondary subsea injection pumps 145, and/or other components of the subsea mechanical dispersion system 100.

The electrical cable 197 can have one or more of a number (e.g., one, two, three, four, 16, 20, 32) of electrical conductors. Each electrical conductor of the electrical cable 197 can be made of one or more of a number of electrically conductive materials, including but not limited to copper and aluminum. Each electrical conductor can be of the size (e.g., 12 AWG, 8 AWG, 16 AWG) needed to carry the power, control, data, and/or other signals between the power source 196 and the load (e.g., the subsea injection pump 140) of the subsea mechanical dispersion system 100. The electrical cable 197 can be any length (e.g., 100 feet, 1000 feet, 10000 feet, 30000 feet) to span the distance between the power source 196 and the load of the subsea mechanical dispersion system 100. Each electrical conductor and the electrical cable 197 can be surrounded by a jacket made of one or more of a number of electrically non-conductive material, including but not limited to rubber and nylon. The electrical cable 197 can be configured to operate in a subsea environment for an extended period of time (e.g., days, weeks, months, years).

The dispersion device 110, including its various components, are designed to operate in a subsea environment for an extended period of time (e.g., days, weeks, months, years). Further, the dispersion device 110, including its various components, are designed to operate under the pressures, turbulence, temperatures, and other conditions that are present at the source of a blowout. Specifically, the dispersion device 110, including its various components, are designed to operate during an active blowout while located at the top end of a remainder of a subterranean string that remains after the blowout and sits above the seabed.

The base 120 of the dispersion device 110 is configured to provide a flow path of the fluid 111 from the piping 148 to the bails 180. In addition, the base 120 of the dispersion device 110 is configured to abut against or affix to the outer surface of a portion of a mandrel at the top end of a remainder of a subterranean string (e.g., casing string, tubing string, wellhead, subsea Xmas tree, BOP, riser) that remains after a blowout and sits above the seabed. The base 120 can be a single piece or multiple pieces that are coupled to each other. More details about how the base 120 may be configured according to certain example embodiments are discussed below with respect to FIGS. 7A through 12B.

The securing mechanism 130 of the dispersion device 110 is configured to be coupled to the base 120. Further, the securing mechanism 130 of the dispersion device 110 is configured to have an engaged position. When the securing mechanism 130 is in the engaged position, the securing mechanism 130 is configured to affix the base 120 to the outer surface of a mandrel at a top end of a remainder of a subterranean string. In some cases, the securing mechanism 130 includes a locking feature that keeps the securing mechanism 130 in the engaged position. More details about how the securing mechanism 130 may be configured according to certain example embodiments are discussed below with respect to FIGS. 7A through 12B.

The one or more bails 180 of the dispersion device 110 are configured to distribute and disburse the fluid 111 toward the oil that emits from the mandrel at a top end of a remainder of a subterranean string. The dispersion device 110 may have a single bail 180 or multiple bails 180. When there are multiple bails 180, the configuration (e.g., shape, adjustability, number of nozzles, location of nozzles) of one bail 180 may be the same as, or different than, the configuration of one or more of the other bails 180. More details about how a bail 180 may be configured according to certain example embodiments are discussed below with respect to FIGS. 2A through 12B.

FIGS. 2A and 2B show an example of a bail 280 of an example subsea mechanical dispersion system according to certain example embodiments. Specifically, FIG. 2A shows a front view of part (toward the distal end) of the bail 280, and FIG. 2B shows a sectional side view of the bail 280 of FIG. 2A. Referring to the description above with respect to FIG. 1, the bail 280 includes a bail wall 281 that forms a channel 282. The bail wall 281 may have any of a number of cross-sectional shapes and/or sizes. For example, in this case, the bail wall 281 has a rectangular cross-sectional shape. Examples of other cross-sectional shapes of the bail wall 281 may include, but are not limited to, a circle, an oval, a triangle, a hexagon, an octagon, and a random shape.

The cross-sectional shape and/or size of the bail wall 281 of the bail 280 may be substantially the same along its length. Alternatively, the cross-sectional shape and/or the size of the bail wall 281 of the bail 280 may vary along at least some of its length. The bail wall 281 of the bail 280 may be linear along some or all of its length. Alternatively, the bail wall 281 of the bail 280 may have some curvature along some or all of its length.

The bail 280 may have any of a number of nozzles 290 in the bail wall 281, oriented directionally along any angle to the medial axis of the bail. In this case, there are optionally N nozzles 290 (nozzle 290-1 through nozzle 290-N) in the bail wall 281. When there are multiple nozzles 290 in the bail wall 281, the nozzles 290 may have the same characteristics (e.g., shape, size, dispersion pattern, dispersion range) relative to each other. For example, in this case, the nozzles 290 have the same circular shape. Alternatively, when there are multiple nozzles 290 in the bail wall 281, the characteristics of one nozzle 290 may be substantially the same as, or different than, the corresponding characteristics of one or more of the other nozzles 290.

Further, the nozzles 290 may be evenly spaced (as in this example) or spaced in some other fashion relative to each other along the bail wall 281 of the bail 280. A nozzle 290 may be positioned at any location (e.g., laterally, radially) on the bail 280. When the bail 280 has multiple nozzles 290, the nozzles 290 may be arranged in some organized manner (e.g., linearly (as in this case), along an arc, equidistantly relative to each other) or randomly. In certain example embodiments, a nozzle 290 may be adjustable relative to the bail wall 281 of the bail 280. For example, in this case, each nozzle 290 of the bail 280 is individually adjustable in any direction (e.g., up and down, side to side). Each nozzle 290 may be adjusted manually, as by a user on a platform or by an ROV in the subsea. In alternative embodiments, when the bail 280 includes multiple nozzles 290, one or more of the nozzles 290 may be adjustable (e.g., fully, in a limited fashion), while a remainder of the nozzles 290 may not be adjustable.

FIGS. 3A and 3B show another example of a bail 380 of an example subsea mechanical dispersion system according to certain example embodiments. Specifically, FIG. 3A shows a front view of part (toward the distal end) of the bail 380, and FIG. 3B shows a sectional side view of the bail 380 of FIG. 3A. Referring to the description above with respect to FIGS. 1 through 2B, the bail 380 includes a bail wall 381 that forms a channel 382. In this case, the bail wall 381 has an oval cross-sectional shape.

In this case, there are optionally M nozzles 390 (nozzle 390-1 through nozzle 390-M) in the bail wall 381. In this case, the nozzles 390 have the same diamond shape and other characteristics (e.g., dispersion pattern, dispersion range), and each nozzle 390 of the bail 380 is individually adjustable in any direction (e.g., up and down, side to side). Further, the nozzles 390 are substantially evenly spaced relative to each other along the bail wall 381 of the bail 380. Each nozzle 390 may be adjusted manually and independently, as by a user on a platform or by an ROV in the subsea.

FIGS. 4 through 6 show other examples of a bail of example subsea mechanical dispersion systems according to certain example embodiments. Specifically, FIG. 4 shows a side view of part of a bail 480. FIG. 5 shows a side view of part of another bail 580. FIG. 6 shows a side view of part of yet another bail 680. The parts of the bail shown in FIGS. 4 through 6 may apply to any section (e.g., a proximal portion that extends upward from the top end of the base (e.g., base 120) of the dispersion device (e.g., dispersion device 110), a distal portion of the bail, somewhere in between the distal and proximal portions of the bail), or multiple sections, of a bail along its length. Referring to the description above with respect to FIGS. 1 through 3B, the bail 480 of FIG. 4 includes a bail wall 481. The nozzles (e.g., nozzles 290) are not visible in this view. FIG. 4 may show a side arm of the bail 480. Alternatively, FIG. 4 may show a distal end of the bail 480 that has a closed distal end.

The bail 580 of FIG. 5 includes a bail wall 581. The nozzles (e.g., nozzles 290) are not visible in this view. FIG. 5 may show a side arm of the bail 580. Alternatively, FIG. 5 may show a distal end of the bail 580 that has a closed distal end. In this case, the bail wall 581 is extendable. Specifically, the bail wall 581 has two portions (bail wall 581-1 and bail wall 581-2) where bail wall 581-2 is slidably disposed within bail wall 581-1. Those of ordinary skill in the art will appreciate that there are other ways in which the length of a bail wall 581 (or portions thereof) may be extended and/or retracted.

The bail 680 of FIG. 6 includes a bail wall 681. The nozzles (e.g., nozzles 290) are not visible in this view. FIG. 6 may show a side arm of the bail 680. Alternatively, FIG. 6 may show a distal end of the bail 680 that has a closed distal end. In this case, the bail wall 681 is extendable. Specifically, the bail wall 681 has two portions (bail wall 681-1 and bail wall 681-2) that are hingedly coupled to each other so that bail wall 681-2 is rotatable relative to bail wall 681-1. Those of ordinary skill in the art will appreciate that there are any of a number of ways in which the angle formed between portions of a bail wall 681 may be adjusted. Similar features may be used to allow for an adjustment of the angle that the proximal end of the bail 680 makes with the base (e.g., base 120) of the dispersion device (e.g., dispersion device 110).

FIGS. 7A and 7B show an example of a dispersion device 710 according to certain example embodiments. Specifically, FIG. 7A shows a side view of the dispersion device 710, and FIG. 7B shows a top sectional view of the dispersion device 710. Referring to the description above with respect to FIGS. 1 through 6, the dispersion device 710 of FIGS. 7A and 7B includes two bails 780 (bail 780-1 and bail 780-2), a base 720, and a securing mechanism 730. With variations discussed below, each bail 780, the base 720, and the securing mechanism 730 of the dispersion device 710 are substantially the same as the bails, the bases, and the securing mechanisms of the dispersion devices discussed above.

In this case, the two bails 780 of the dispersion device 710 of FIGS. 7A and 7B are configured substantially the same as each other. Each bail 780 extends upward from opposing ends of the top of the base 720. Each bail 780 also then extends inward at an angle that is slightly more than 90 degrees. In such a case, the transition can range from an abrupt angle to a smooth arc along most of the length of the bail 780. In some cases, the angle that a bail 780 forms between its proximal end and its distal end may be adjusted by a user (e.g., an engineer above the waterline, an ROV in the subsea). In addition, or on the alternative, the distance that a bail 780 extends away from the top of the base 720 before extending inward may be adjusted by a user. Each side of each bail 780 has four nozzles 790 (specifically, a total of 8 nozzles 790-1 on bail 780-1 and a total of 8 nozzles 790-2 on bail 780-2) that are spaced substantially equidistantly from each other along the lateral extension of the bail 780. Each nozzle 790 may be individually adjustable by a user (e.g., an engineer above the waterline, an ROV in the subsea).

The base 720 of the dispersion device 710 has an outer wall 721 and an inner wall 723 that are concentric with each other, forming a cavity 722 (also sometimes called a base cavity 722) in between. The cavity 722 between the outer wall 721 and the inner wall 723 is designed to allow fluid (e.g., fluid 111) received at the inlet 725 to flow therethrough. In this way, fluid that enters the inlet 725 (e.g., through piping 148) flows continuously through the cavity 722 in the base 720, through the channels (e.g., similar to the channels 282 discussed above) formed by the walls 781 of the bails 780, and out the nozzles 790 in the bails 780.

The inner wall 723 of the base 720 forms an opening 724 into which a mandrel at the top end of a subterranean string that remains after a blowout may be disposed. The inner surface of the inner wall 723 of the base 720 may include one or more of a number of contact features (e.g., texturing, sawtooth features, a tacky substance) that help ensure that the inner wall 723 of the base 720 abuts against and maintains contact with the mandrel when the securing mechanism 730 is engaged with the mandrel disposed in the opening 724.

The base 720 of the dispersion device 710 may have any of a number of features and/or configurations to allow the base to be disposed around a mandrel during a blowout using an ROV. For example, the base 720 may be a single piece that is positioned over the mandrel and then is moved downward before the securing mechanism 730 is engaged. As another example, the base 720 may have multiple pieces that are coupled (e.g., hingedly, using slots and tabs) to each other so that the base 720 wraps around the mandrel before the securing mechanism 730 is engaged.

The securing mechanism 730 of the dispersion device 710 is designed to help ensure that the base 720 maintains a substantially fixed position around the mandrel so that the position of the nozzles of the bails 780 remains substantially fixed relative to the oil released into the water. The securing mechanism 730 may have one or more of any of a number of configurations. For example, the securing mechanism 730 may include one or more set screws that are driven into the outer wall 721 of the base 720. As another example, the securing mechanism 730 may include one or more latches that operate using, for example, a handle and a cam. In any case, the securing mechanism 730 may be designed to engage and/or disengage using an ROV while in the water near the seabed.

In some cases, the dispersion device 710 has multiple securing mechanisms 730. In such cases, the configuration of one securing mechanism 730 may be the same as, or different than, the configuration of one or more of the other securing mechanisms 730. In certain example embodiments, a securing mechanism 730 may include a locking feature that keeps the securing mechanism 730 in the engaged position. In such cases, the locking feature may be configured to be engaged using an ROV while in the water near the seabed.

FIGS. 8 and 9 show a top view of other examples of dispersion devices according to certain example embodiments. Specifically, FIG. 8 shows a top view of a dispersion device 810, and FIG. 9 shows a top view of another dispersion device 910. Referring to the description above with respect to FIGS. 1 through 7B, the dispersion device 810 of FIG. 8 includes two bails 880 (bail 880-1 and bail 880-2), a base 820, and a securing mechanism 830. Similarly, the dispersion device 910 of FIG. 9 includes three bails 980 (bail 980-1, bail 980-2, and bail 980-3), a base 920, and a securing mechanism 930. With variations discussed below, each bail, base, and securing mechanism of the dispersion devices of FIGS. 8 and 9 are substantially the same as the bails, the bases, and the securing mechanisms of the dispersion devices discussed above.

For the dispersion device 810 of FIG. 8, the two bails 880 are configured substantially the same as each other. Each bail 880 extends upward from opposing ends of the top of the base 820. Each bail 880 also then extends inward at an angle. In such a case, the transition can range from an abrupt angle to a smooth arc along most of the length of the bail 880. In some cases, the angle that a bail 880 forms between its proximal end and its distal end may be adjusted by a user (e.g., an engineer above the waterline, an ROV in the subsea). In addition, or on the alternative, the distance that a bail 880 extends away from the top of the base 820 before extending inward may be adjusted by a user. Each side of each bail 880 has three nozzles 890 (specifically, a total of six nozzles 890-1 on bail 880-1 and a total of six nozzles 890-2 on bail 880-2) that are spaced substantially equidistantly from each other along the lateral extension of the bail 880. Each nozzle 890 may be individually adjustable by a user (e.g., an engineer above the waterline, a ROV in the subsea).

The base 820 of the dispersion device 810 has an outer wall 821 and an inner wall 823 that are concentric with each other, forming a cavity (hidden from view) in between. The cavity between the outer wall 821 and the inner wall 823 is designed to allow fluid (e.g., fluid 111) received at the inlet 825 to flow therethrough. In this way, fluid that enters the inlet 825 (e.g., through piping 148) flows continuously through the cavity in the base 820, through the channels (e.g., similar to the channels 282 discussed above) formed by the walls 881 of the bails 880, and out the nozzles 890 in the bails 880.

The inner wall 823 of the base 820 forms an opening 824 into which a mandrel at the top end of a subterranean string that remains after a blowout may be disposed. The inner surface of the inner wall 823 of the base 820 may include one or more of a number of features (e.g., texturing, sawtooth features, a tacky substance) that helps ensure that the inner wall 823 of the base 820 abuts against the mandrel when the securing mechanism 830 is engaged with the mandrel disposed in the opening 824.

The base 820 of the dispersion device 810 may have any of a number of features and/or configurations to allow the base to be disposed around a mandrel during a blowout using a ROV. In this case, the base 820 is made up of two pieces that are coupled to each other by a hinge 829 so that the base 820 wraps around the mandrel before the securing mechanism 830 is engaged. In this way, some of the securing mechanism 830 may be on one of the pieces of the base 820, while a remainder of the securing mechanism 830 may be on the other piece of the base 820. The securing mechanism 830 may be designed to engage and/or disengage using an ROV while in the water near the seabed.

For the dispersion device 910 of FIG. 9, the three bails 980 are configured substantially the same as each other. Each bail 980 extends upward from points substantially equidistantly along the top of the base 920. Each bail 980 also then extends inward at an angle along a tangent. In some cases, the angle (e.g., tangential, lateral) that a bail 980 forms between its proximal end and its distal end may be adjusted by a user (e.g., an engineer above the waterline, a ROV in the subsea). In addition, or on the alternative, the distance that a bail 980 extends away from the top of the base 920 before extending inward and/or tangentially may be adjusted by a user. One side of each bail 980 has one elongated nozzle 990 (specifically, one nozzle 990-1 on bail 980-1, one nozzle 990-2 on bail 980-2, and one nozzle 990-3 on bail 980-3) along the lateral extension of the bail 980. Each nozzle 990 may be individually adjustable by a user (e.g., an engineer above the waterline, an ROV in the subsea).

The base 920 of the dispersion device 910 has an outer wall 921 and an inner wall 923 that are concentric with each other, forming a cavity (hidden from view) in between. The cavity between the outer wall 921 and the inner wall 923 is designed to allow fluid (e.g., fluid 111) received at the inlet 925 to flow therethrough. In this way, fluid that enters the inlet 925 (e.g., through piping 148) flows continuously through the cavity in the base 920, through the channels (e.g., similar to the channels 382 discussed above) formed by the walls 981 of the bails 980, and out the nozzles 990 in the bails 980.

The inner wall 923 of the base 920 forms an opening 924 into which a mandrel at the top end of a subterranean string that remains after a blowout may be disposed. The inner surface of the inner wall 923 of the base 920 may include one or more of a number of features (e.g., texturing, sawtooth features, a tacky substance) that helps ensure that the inner wall 923 of the base 920 abuts against the mandrel when the securing mechanism 930 is engaged with the mandrel disposed in the opening 924.

The base 920 of the dispersion device 910 may have any of a number of features and/or configurations to allow the base to be disposed around a mandrel during a blowout using an ROV. In this case, the base 920 is made up of two pieces that are coupled to each other by a hinge 929 so that the base 920 wraps around the mandrel before the securing mechanism 930 is engaged. In this way, some of the securing mechanism 930 may be on one of the pieces of the base 920, while a remainder of the securing mechanism 930 may be on the other piece of the base 920. The securing mechanism 930 may be designed to engage and/or disengage using an ROV while in the water near the seabed.

FIGS. 10A and 10B show another example of part of a system 1099 that includes a subsea mechanical dispersion system 1000 according to certain example embodiments. Specifically, FIG. 10A shows a front view of the part of the system 1099, and FIG. 10B shows a close up front view that includes the dispersion device 1010 of the subsea mechanical dispersion system 1000 of FIG. 10A. Referring to the description above with respect to FIGS. 1 through 9, the system 1099 shows the subsea mechanical dispersion system 1000 located in water 1066 at the seabed 1005. The subsea mechanical dispersion system 1000 of FIG. 10A includes a subsea injection pump 1040, a secondary subsea injection pump 1045, a storage container 1050, the dispersion device 1010, an energy storage device 1095, an electrical cable 1097, and piping 1048 that provides for the flow of fluids between those components. These components are substantially the same as the corresponding components of the subsea mechanical dispersion systems discussed above.

The subsea injection pump 1040 of the subsea mechanical dispersion system 1000 is positioned on the seabed 1005. In this case, the subsea injection pump 1040 is a high pressure, high volume pump that is configured to pump fluid 1041 in the form of water 1066 from the surrounding subsea into the piping 1048 connected to the output of the subsea injection pump 1040. The subsea injection pump 1040 is fed by power flowing through an electrical cable 1097, where the power is generated from a power source (e.g., power source 196) above the water 1066.

The secondary subsea injection pump 1045 is also positioned on the seabed 1005. In this case, the secondary subsea injection pump 1045 may have a lower volume rating relative to the volume rating of the subsea injection pump 1040. The secondary subsea injection pump 1045 may nevertheless be equipped with a pressure rating sufficient to inject fluid from the storage container 1050 into the flowstream in the piping 1048 from the subsea injection pump 1040. The secondary subsea injection pump 1045 is configured to pump fluid 1046 in the form of a surfactant and/or a dispersant from the storage container 1050 into the piping 1048 connected to the output of the secondary subsea injection pump 1045. The secondary subsea injection pump 1045 may receive power from the energy storage device 1095. In addition, or in the alternative, the secondary subsea injection pump 1045 may receive power from a power source (e.g., power source 196) through the electrical cable 1097. In such a case, the power source may be located in the water 1066 or outside the water 1066 (e.g., on a platform, ship, or other vessel).

The fluid 1041 and the fluid 1046 combine and mix at the junction 1049 of the piping 1048 to form fluid 1011, which is delivered to the inlet 1025 of the dispersion device 1010. Upon entering the inlet, the fluid 1011 flows through the base of the dispersion device 1010, through the bails 1080 of the dispersion device 1010, and out the nozzles 1090 in the bails 1080. In this way, there is a continuous flow path from the inlet 1025 to the nozzles 1090 within the dispersion device 1010.

The dispersion device 1010 of FIGS. 10A and 10B has two bails 1080 (bail 1080-1 and bail 1080-2) that split off from a common pair of vertical segments that extend from opposite ends of the top of the base 1020 of the dispersion device 1010. The two bails 1080 are configured substantially the same as each other. Each bail 1080 extends inward from the pair of vertical segments along an arc. Each bail 1080 has nine nozzles 1090 that point inward. The nozzles 1090 are spaced substantially equidistantly from each other along the arc formed by each bail 1080. Each nozzle 1090 may be individually adjustable by a user (e.g., an engineer above the waterline, an ROV in the subsea).

In certain example embodiments, as in this case, one or more of the bails 1080 of the dispersion device 1010 may include one or more of a number of lifting devices 1069. In this case, there are two lifting devices 1069 (lifting device 1069-1 and lifting device 1069-2) that extend from each of the pair of vertical segments of the bail 1080. A lifting device 1069 may have any of a number of configurations that allow some or all of the dispersion device 1010 to be manipulated (e.g., lifted, rotated, lowered, tilted) by a ROV (e.g., using a clamp) and/or other lifting device (e.g., a crane on a vessel). When a lifting device 1069 is coupled to a bail 1080, the lifting device 1069 may be positioned below where the bail 1080 has adjustability features and/or above the center of gravity of the dispersion device 1010.

Examples of a lifting device 1069 may include, but are not limited to, a pad eye, an eye nut, and an eye bolt. A lifting device 1069 may be directly or indirectly coupled to a bail 1080 using any of a number of coupling features (e.g., mating threads, welding). When the dispersion device 1010 includes multiple lifting devices 1069, the configuration (e.g., shape, size, method of coupling, material, location on the bail 1080) of one lifting device 1069 may be the same as, or different than, the corresponding configuration of one or more of the other lifting devices 1069. In some cases, when the dispersion device 1010 includes one or more lifting devices 1069, such one or more lifting devices 1069 may additionally or alternatively be coupled to another component (e.g., the base 1020) of the dispersion device 1010.

The base 1020 of the dispersion device 1010 has an outer wall 1021 and an inner wall (hidden from view) that are concentric with each other, forming a cavity (hidden from view) in between. The cavity between the outer wall 1021 and the inner wall is designed to allow fluid 1011 received at the inlet 1025 to flow therethrough. The inner wall of the base 1020 forms an opening (e.g., similar to opening 824) into which the mandrel 1001 at the top end of a subterranean string that remains after a blowout is positioned. The inner surface of the inner wall of the base 1020 may include one or more of a number of features (e.g., texturing, sawtooth features, a tacky substance) that helps ensure that the inner wall of the base 1020 abuts against the mandrel when the securing mechanism (hidden from view) is engaged with the mandrel disposed in the cavity.

FIG. 11 shows another example of part of a system 1199 that includes a dispersion device 1110 according to certain example embodiments. Referring to the description above with respect to FIGS. 1 through 10B, the system 1199 shows the dispersion device 1110 located in water 1166 at the seabed 1105. The dispersion device 1110 of FIG. 11 includes an inlet 1125, a base 1120, a securing mechanism 1130, two bails 1180 (bail 1180-1 and bail 1180-2), and 8 nozzles 1190 (four nozzles 1190 on each bail 1180). These components are substantially the same as the corresponding components of the dispersion devices discussed above.

The two bails 1180 split off from a common pair of vertical segments that extend from opposite ends of the top of the base 1120 of the dispersion device 1110. The two bails 1180 are configured substantially the same as each other. Each bail 1180 extends inward from the pair of vertical segments along an arc. Each bail 1180 has four nozzles 1190 that are spaced substantially equidistantly from each other along the arc formed by each bail 1180. Each nozzle 1190 in this example is individually adjustable by a user (e.g., an engineer above the waterline, a ROV in the subsea). Also in this case, the bails 1180 include an adjustment mechanism 1189 located where the distal ends of both bails 1180 rejoin. The adjustment mechanism 1189 in this example is in the form of a rotary dial that simultaneously adjusts the angle of separation between the two bails 1180 within a fixed range (e.g., between 10° and 170°). The adjustment mechanism 1189 may be manipulated by a user (e.g., a person above the water 1166, an ROV in the water 1166).

In certain example embodiments, any adjustment mechanisms 1189 for the bails 1180 are located above or toward the distal end of the common pair of vertical segments of the bails 1180. For example, an adjustment mechanism 1189 may be located some distance (e.g., 6 feet, 20 feet) above the top of the base 1120 of the dispersion device 1110. In this way, the common pair of vertical segments of the bails 1180 may be fixed strongly and directly to the base 1120. The various adjustments to the bails 1180 and the nozzles 1190 may be made so that the nozzles 1190 are some distance (e.g., 10 times the diameter of the mandrel 1101, from 3 to 20 feet) from the opening (e.g., vertically, laterally) of the blowout so that the fluid (e.g., fluid 111) expelled from the nozzles 1190 may have optimal effectiveness in terms of dispersing the oil that is emitted from the mandrel 1101.

The base 1120 of the dispersion device 1110 has an outer wall 1121 and an inner wall (hidden from view) that are concentric with each other, forming a cavity (hidden from view) in between. The cavity between the outer wall 1121 and the inner wall is designed to allow fluid (e.g., fluid 111) received at the inlet 1125 to flow therethrough. In this way, fluid that enters the inlet 1125 (e.g., through piping 148) flows continuously through the cavity in the base 1120, through the channels (e.g., similar to the channels 282 discussed above) formed by the walls 1181 of the bails 1180, and out the nozzles 1190 in the bails 1180.

The inner wall of the base 1120 forms an opening (hidden from view) into which the mandrel 1101 at the top end of the subterranean string 1102 that remains after a blowout is located. Most of the subterranean string 1102 is below the seabed 1105 within the subterranean formation 1109. The inner surface of the inner wall of the base 1120 may include one or more of a number of features (e.g., texturing, sawtooth features, a tacky substance) that helps ensure that the inner wall of the base 1120 abuts against the mandrel 1101 when the securing mechanism 1130 is engaged with the mandrel 1101 disposed in the cavity. In this case, the securing mechanism 1130 is in the form of a clamp that is configured to be engaged and hold in water 1166 near the seabed 1105.

FIGS. 12 through 15 show an example of a system 1299 that implements a subsea mechanical dispersion system 1200 in the field according to certain example embodiments. Specifically, FIG. 12 shows the system 1299 at a point in time after a blowout occurs and while the subsea mechanical dispersion system 1200 is being moved to the location of the blowout. FIG. 13 shows the system 1299 at a point in time subsequent to the time in FIG. 12 in which the subsea mechanical dispersion system 1200 is placed on the seabed 1205. FIG. 14 shows the system 1299 at a point in time subsequent to the time in FIG. 13 in which the dispersion device 1210 is positioned on the mandrel 1201. FIG. 15 shows the system 1299 at a point in time subsequent to the time in FIG. 14 in which the subsea mechanical dispersion system 1200 is operating to disperse the oil 1206.

In addition to the subsea mechanical dispersion system 1200, the system 1299 includes a floating vessel 1203 that floats in the water 1266 (e.g., seawater) at the waterline 1293. In this case, the vessel 1203 is a ship (e.g., an offshore construction vessel) designed for use in subsea field operations. In alternative embodiments, the vessel 1203 may have any of a number of other forms, including but not limited to a semi-submersible rig, a jack-up rig, and a land-based facility that is located close to the location in the water 1266 at the seabed 1205 where the blowout occurred. The vessel 1203 includes a lifting apparatus 1217 (e.g., a crane) and a power source 1296. The lifting apparatus 1217 is configured to lower, through a cable 1207, a basket 1298, skid, or similar apparatus in which the subsea mechanical dispersion system 1200 is placed into the water 1266 and to the seabed 1205 in a controlled fashion (e.g., in terms of rate of descent, in terms of placement relative to the mandrel 1201). The power source 1296 is substantially the same as the power sources discussed above and is configured to provide power to one or more electrical devices.

Also included in the system 1299 is the mandrel 1201 at the top end of the subterranean string 1202 that remains after a blowout. Since the point along the subterranean string 1202 at which the blowout occurs may vary, the mandrel 1201 may be any of a number of different subsea components of the subterranean string 1202. Examples of such subsea components may include, but are not limited to, a tubing pipe of a tubing string, a casing pipe of a casing string, the BOP, part of the riser, or the wellhead. Most of the subterranean string 1202 is below the seabed 1205 within the subterranean formation 1209. As a result of the blowout, oil 1206 is being emitted out the mandrel 1201 toward the waterline 1293. The oil 1206 largely stays together in the water 1266 until reaching the waterline 1293, where the oil 1206 spreads out. There can be any distance (e.g., a few hundred feet, a few thousand feet, a few tens of thousands of feet) between the seabed 1205 and the waterline 1293.

As captured in FIG. 12, the blowout has occurred, and oil is emitted to the waterline 1293. The lifting apparatus 1217 controls a cable 1207 coupled to the basket 1298 and is used to lower the subsea mechanical dispersion system 1200 positioned within the basket 1298 in the water 1266 to the seabed 1205. In addition, an ROV 1219 is in the water 1266 and controlled in such a way as to accompany the subsea mechanical dispersion system 1200 in its descent to the seabed 1205. Also, an electrical cable 1297 that is coupled at one end to the power source 1296 and at the other end to the subsea injection pump 1240 of the subsea mechanical dispersion system 1200 is in the water 1266 and joins the descent of the subsea mechanical dispersion system 1200 to the seabed 1205.

The ROV 1219 may receive power signals 1263 from one or more energy storage devices (e.g., similar to the energy storage devices 195 discussed above) and/or one or more power sources (e.g., similar to the power source 196 discussed above) onboard the ROV 1219. In addition, or in the alternative, the ROV 1219 may receive power signals 1263 from the power source 1296 located on the vessel 1203 through an electrical cable (e.g., similar to electrical cable 1297. The ROV 1219 may be controlled automatically by an onboard controller. In addition, or in the alternative, the ROV 1219 may transmit signals (e.g., control signals, data signals) with a communication/control device located on the vessel 1203 using one or more communication links 1262. In such a case, each communication link 1262 can include wired (e.g., Class 1 electrical cables, Class 2 electrical cables, electrical connectors, power line carrier) and/or wireless (e.g., Wi-Fi, visible light communication, cellular networking, visible light communication (VLC), 802.15.4 wireless, ZigBee, 4G cellular wireless, ultrawide band (UWB), Bluetooth, WirelessHART, ISA100, sound wave) technology.

As captured in FIG. 13, the basket 1298 with the subsea mechanical dispersion system 1200 is resting on the seabed 1205, and the ROV 1219 is nearby. The ROV 1219 is used to disconnect the distal ends of the cable 1207 from the basket 1298, and the lifting apparatus 1217 retrieves the cable 1207 to the vessel 1203. The oil 1206 continues to be emitted from the mandrel 1201 toward the waterline 1293.

As captured in FIG. 14, the ROV 1219 has secured the dispersion device 1210 from the basket 1298 and moved the dispersion device 1210 to be coupled around the mandrel 1201 toward its top end that is now exposed after the blowout. For this to occur, the piping 1248 between the dispersion device 1210 and the subsea injection pump 1240 (and possibly other components (e.g., the secondary subsea injection pump 1245) of the subsea mechanical dispersion system 1200) is flexible rather than rigid.

The ROV 1219 may be powerful enough to lift and manipulate the dispersion device 1210 while being exposed to prevailing currents at the seabed 1205 and turbulence generated by the oil 1206 being emitted from the mandrel 1201. In addition to moving the dispersion device 1210, the ROV 1219 may be able to manipulate the base, the securing mechanism, the locking feature, the bails 1280, and the nozzles of the dispersion device 1210 to ensure that the dispersion device 1210 is secured in place relative to the mandrel 1201 and to ensure that the fluid (e.g., fluid 111) that flows out of the nozzles of the dispersion device 1210 may effectively counteract (e.g., disperse, chemically alter) the oil 1206.

As captured in FIG. 15, the subsea mechanical dispersion system 1200 is operating. Specifically, after the ROV 1219 has made all of the adjustments (e.g., adjusting the position of one or more of the nozzles relative to its respective bail 1280, adjusting the height 1267 of one or more of the bails 1280 relative to the top of the mandrel 1201, adjusting the angle of a bail 1280 relative to the base (e.g., similar to the base 1020) of the dispersion device 1210, putting the securing mechanism (e.g., similar to the securing mechanism 1030) of the dispersion device 1210 in the engaged position) to the dispersion device 1210, the subsea injection pump 1240, powered by the power source 1296 through the electrical cable 1297, pumps a fluid (e.g., fluid 141) in the form of water 1266 into the piping 1248.

Simultaneously, the secondary subsea injection pump 1245, powered by the energy storage device 1295, pumps a fluid (e.g., fluid 146) (e.g., in the form of a surfactant, in the form of a dispersant) from the storage container 1250 through the piping 1248. The fluids pumped by the subsea injection pump 1240 and the secondary subsea injection pump 1245 mix in the piping 1248 to form a combined fluid (e.g., fluid 111) that is delivered to the inlet (e.g., inlet 1125) of the dispersion device 1210. This combined fluid flows through the dispersion device 1210 and out the nozzles in the bails 1280 to interact with the oil 1206 in the water 1266. The result, as shown in FIG. 15, is that the oil is greatly dispersed and has little accumulation at the waterline 1293.

The subsea mechanical dispersion system 1200 may be configured to operate substantially continuously in this subsea environment for an extended period of time (e.g., 60 days, 90 days, 6 months, a year). When the subsea operation involving the subsea mechanical dispersion system 1200 is complete (e.g., the blowout has been completely sealed off), the ROV 1219 may be used to disengage the locking mechanism (if any) and the securing mechanism of the dispersion device 1210 so that the subsea mechanical dispersion system 1200 may be retrieved (e.g., by the lifting apparatus 1217 using the cable 1207) to the platform for use on a future blowout.

In some cases, example embodiments may be directed to a dispersion device of a subsea mechanical dispersion system. In such cases, the dispersion device may include a base having an inlet and a base wall forming a base cavity, where the inlet is configured to couple to piping that provides a fluid, propelled by a subsea pump, to the base cavity. Such a dispersion device may also include a securing mechanism coupled to the base wall, where the securing mechanism, when in an engaged position, is configured to affix the base to an outer surface of a mandrel at a top end of a remainder of a subterranean string. Such a dispersion device may further include a bail having a bail wall that forms a channel, where the channel is continuous with the base cavity through a nozzle at its distal end, and where the channel and the base cavity provide a continuous path from the inlet to the nozzle.

In some cases, the bail of such an example dispersion device may be adjustable relative to the base. In addition, or in the alternative, the bail of such an example dispersion device may have a closed distal end. In addition, or in the alternative, the bail (or portion thereof) of such an example dispersion device may form a closed loop. In addition, or in the alternative, the bail of such an example dispersion device may include at least one additional nozzle along its length. In such cases, the nozzle and the at least one additional nozzle may be independently adjustable.

In addition, or in the alternative, the base of such an example dispersion device may include multiple pieces that are coupled to each other. In addition, or in the alternative, in such cases, the multiple pieces of the base may be hingedly coupled to each other. In addition, or in the alternative, the securing mechanism of such an example dispersion device may have a locking feature that keeps the securing mechanism in the engaged position. In such cases, the locking feature may be configured to be engaged by an ROV. In addition, or in the alternative, the securing mechanism of such an example dispersion device may be configured to be manipulated between a disengaged position and the engaged position by an ROV.

Example embodiments can be used to safely and effectively disperse (and/or otherwise interact with) oil that is emitted in water after a blowout has occurred. Example embodiments may be installed, manipulated, and/or maintained using an ROV. Example embodiments are configured to operate over extended periods of time in a subsea environment. Example embodiments may be configured for a single use or multiple uses. Example embodiments may comply with applicable industry standards when used during subsea field operations.

Although embodiments described herein are made with reference to example embodiments, it should be appreciated by those skilled in the art that various modifications are well within the scope and spirit of this disclosure. Those skilled in the art will appreciate that the example embodiments described herein are not limited to any specifically discussed application and that the embodiments described herein are illustrative and not restrictive. From the description of the example embodiments, equivalents of the elements shown therein will suggest themselves to those skilled in the art, and ways of constructing other embodiments using the present disclosure will suggest themselves to practitioners of the art. Therefore, the scope of the example embodiments is not limited herein.