AIR-FREIGHTABLE SUBSEA WELL CONTAINENT TOOLING PACKAGE
A system for supplying a chemical dispersant to a subsea hydrocarbon discharge site comprises a surface vessel including a dispersant storage tank and a dispersant pump configured to pump dispersant from the storage tank. In addition, the system comprises a first flow line coupled to the pump and extending subsea from the vessel. Further, the system comprises a subsea dispersant distribution system coupled to the first flow line. Still further, the system comprises a dispersant injection device coupled to the distribution system and configured to inject dispersant from the tank into a subsea hydrocarbon stream.
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This application claims benefit of U.S. provisional patent application Ser. No. 61/502,188 filed Jun. 28, 2011, and entitled “Air-Freightable Subsea Well Containment Tooling Package,” which is hereby incorporated herein by reference in its entirety. This application also claims benefit of U.S. provisional patent application Ser. No. 61/502,200 filed Jun. 28, 2011, and entitled “Air-Freightable Subsea Well Containment Tooling Package,” which is hereby incorporated herein by reference in its entirety.
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENTNot applicable.
BACKGROUND1. Field of the Invention
The invention relates generally to a tooling package deployed as an initial response to a subsea hydrocarbon discharge. More particularly, the invention relates to an air-freightable tooling package including a subsea dispersant injection system for delivering chemical dispersants to a subsea hydrocarbon discharge stream.
2. Background of the Technology
In offshore drilling operations, a blowout preventer (BOP) is often installed on a wellhead at the sea floor and a lower marine riser package (LMRP) mounted to the BOP. In addition, a drilling riser extends from a flex joint at the upper end of LMRP to a drilling vessel or rig at the sea surface. A drill string is then suspended from the rig through the drilling riser, LMRP, and the BOP into the well bore.
During drilling operations, drilling fluid, or mud, is delivered through the drill string, and returned up an annulus between the drill string and casing that lines the well bore. In the event of a rapid influx of formation fluid into the annulus, commonly known as a “kick,” the BOP and/or LMRP may actuate to seal the annulus and control the well. In particular, BOPs and LMRPs comprise closure members capable of sealing and closing the well in order to prevent the release of gas or liquids from the well. However, if the wellbore is not sealed in response to a surge of formation fluid pressure in the annulus, a “blowout” may occur. The blowout may result in the discharge of hydrocarbons into the surrounding sea water. The subsea release of hydrocarbons may present environmental issues. In addition, the subsea release of hydrocarbons may potentially present a hazardous environment at the surface. Consequently, the more time it takes to respond to a subsea blowout and subsea discharge of hydrocarbons, the more hydrocarbons are likely discharged into the surrounding water).
Chemical dispersing agents, or simply dispersants, are specially formulated chemical products containing surface-active agents and a solvent. Dispersants aid in breaking up hydrocarbon solids and liquids by reducing the interfacial tension between the oil and water, thereby promoting the migration of finely dispersed water-soluble micelles that are rapidly diluted. As a result, the hydrocarbons are effectively spread throughout a larger volume of water, and the environmental impact may be reduced. In addition, dispersants are believed to facilitate and accelerate the digestion of hydrocarbons by microbes, protozoa, nematodes, and bacteria. Moreover, the use of dispersants reduces the risk to responders at the surface by minimizing the accumulation of oil, associated volatile organic compounds (VOCs) and hydrocarbon vapors. Dispersants can also delay the formation of persistent oil-in-water emulsions.
Traditionally, dispersants have been sprayed onto the oil at the surface of the water. Normally, this process is controlled and delivered from surface vessels or from the air immediately above the oil at the surface. For example, aircraft may be employed to spray oil dispersant over an oil slick on the surface of the sea. Since dispersants may comprise chemicals, there is generally a desire to minimize the quantity and distribution of dispersants that are used. However, since oil released from a subsea well diffuses and spreads out at it rises to the surface, oil at the surface is often spread out over a relatively large area (e.g., hundreds or thousands of square miles). To sufficiently cover all or substantially all of the oil that reaches the surface, relatively large quantities of dispersant must be distributed over the relatively large area encompassed by the oil slick.
To minimize “overspray” and limit the application of dispersants to the oil slick itself, distribution at the surface typically involves the visualization of the oil slick at the surface. Accordingly, around the clock surface distribution may not be possible (e.g., at night the location and boundaries of the oil slick at the surface may not be visible). However, there is usually a limited time-frame in which dispersants can be successfully applied at the surface. In particular, certain oil constituents evaporate quickly at the surface, leaving waxy residues or “weathered” oil that are often unresponsive to dispersants.
It should also be appreciated that some turbulence at the surface (e.g., wave action) is preferred during surface application of dispersants to sufficiently mix the dispersant into the oil and the treated oil into the water. Depending on the weather and sea conditions, surface turbulence may be less than adequate. Moreover, by limiting distribution of dispersants to the surface, only those microbes at or proximal the surface have an opportunity to begin digestion of the oil.
Accordingly, there remains a need in the art for improved systems and methods for the offshore application of chemical dispersant to discharged hydrocarbons. Such systems and methods would be particularly well received if they were rapidly sourced and easily transported to the offshore location, and further, offered the potential to minimize the quantity of dispersants emitted, enhance dissipation of the discharged oil before it reaches the surface, operate around the clock (e.g., 24 hours a day), and facilitate increased microbial digestion of oil.
BRIEF SUMMARY OF THE DISCLOSUREThese and other needs in the art are addressed in one embodiment by a system for supplying a chemical dispersant to a subsea hydrocarbon discharge site. In an embodiment, the system comprises a surface vessel including a dispersant storage tank and a dispersant pump configured to pump dispersant from the storage tank. In addition, the system comprises a first flow line coupled to the pump and extending subsea from the vessel. Further, the system comprises a subsea dispersant distribution system coupled to the first flow line. The dispersant distribution system includes a modular subsea manifold assembly including a base, a frame removably coupled to the base, and a chemical dispersant manifold coupled to the frame. Still further, the system comprises a dispersant injection device coupled to the distribution system and configured to inject dispersant from the tank into a subsea hydrocarbon stream.
These and other needs in the art are addressed in another embodiment by a subsea manifold assembly. In an embodiment, the manifold assembly comprises a base including a plate and a plurality of posts extending perpendicularly from the plate. In addition, the manifold assembly comprises a frame removably coupled to the base. The frame has an upper end, a lower end, and a plurality of parallel posts extending from the upper end to the lower end. Each post has a receptacle at the lower end that slidingly receives one of the posts of the base. Further, the manifold assembly comprises a chemical dispersant manifold coupled to the frame. The chemical dispersant manifold includes a plurality of dispersant inlets and a plurality of dispersant outlets.
These and other needs in the art are addressed in another embodiment by a method for responding to a subsea hydrocarbon discharge at an offshore location. In an embodiment, the method comprises (a) storing a base of a subsea manifold assembly, a frame of a subsea manifold assembly, a chemical dispersant manifold of the subsea manifold assembly, a flying lead, and a dispersant application device at a common geographical location. In addition, the method comprises (b) transporting the base, the frame, the dispersant manifold, the flying lead, and the application device to the offshore location. Further, the method comprises (c) assembling the base, the frame, and the dispersant manifold into the manifold assembly. Still further, the method comprises (d) lowering the manifold assembly subsea after (c).
Thus, embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods. The various characteristics described above, as well as other features, will be readily apparent to those skilled in the art upon reading the following detailed description, and by referring to the accompanying drawings.
For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings in which:
The following discussion is directed to various embodiments of the invention. Although one or more of these embodiments may be preferred, the embodiments disclosed should not be interpreted, or otherwise used, as limiting the scope of the disclosure, including the claims. In addition, one skilled in the art will understand that the following description has broad application, and the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.
Certain terms are used throughout the following description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not function. The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.
In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . ” Also, the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection, or through an indirect connection via other devices, components, and connections. In addition, as used herein, the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis.
Referring now to
In this embodiment, system 100 includes an offshore support vessel 120 at the sea surface 102, a dispersant distribution system 130 extending along the sea floor 103, and a plurality of subsea dispersant application devices 200 coupled to distribution system 130. In general, support vessel 120 stores chemical dispersants at the sea surface 102 and pumps the chemical dispersants to the distribution system 130. Dispersant in system 130 is then supplied to application devices 200, which are employed by one or more subsea remotely operated vehicles (ROVs) 290 to inject the dispersant into the hydrocarbon stream 111 emitted at discharge site 110.
Vessel 120 includes a plurality of chemical dispersant storage tanks 121, a plurality of dispersant injection pumps 122 coupled to tanks 121, and a dispersant flow line 124 extending from pumps 122 to distribution system 130. In this embodiment, flow line 124 is coiled tubing mounted to a coiled tubing reel or unit 123 that supplies the dispersants to distribution system 130 and application devices 200. In other embodiments, flow line 124 may be a subsea umbilical that supplies the dispersants to distribution system 130 and application devices 200, and may also supply electrical power and pressurized hydraulic fluid to system 130. Such an umbilical may be mounted to a reel or stored and deployed in another suitable fashion.
Tanks 121 store chemical dispersants at the sea surface 102 on vessel 120. In this embodiment, three tanks 121 are provided, each tank 121 being the same. Namely, each tank 121 comprises a five-thousand gallon dispersant storage vessel. However, in general, tanks 121 may comprise any suitable number and size dispersant storage tanks Further, the chemical dispersant stored in tanks 121 and supplied to system 130 may comprise any suitable chemical dispersant including, without limitation, a surfactant or mixture of fluids including surfactants. One example of a suitable chemical dispersant is Corexit® EC9500A available from Nalco Company of Naperville, Ill.
Pumps 122 supply dispersant in tanks 121 to coiled tubing 124 of coiled tubing unit 123. In this embodiment, one fluid pump 122 is provided for each storage tank 121, and thus, each pump 122 pulls dispersant from one tank 121 and supplies it to coiled tubing unit 123 and associated coiled tubing 124. In addition, in this embodiment, each pump 122 includes a flowmeter to measure and monitor the volumetric flow rate of dispersant through that pump 122. Pumps 122 preferably operate at pressures and flow rates suitable for the downstream components of system 100. In this embodiment, each pump 122 is configured to output dispersant at a pressure less than or equal to 5,000 psi and flow rate less than or equal to 12 gpm. However, in other embodiments, the pressure and flow rate of dispersant from pumps 122 may be increased or decreased depending on the limitations of the downstream components. Coiled tubing 124 extends from coiled tubing unit 123 and vessel 120 at the sea surface 102 to subsea distribution system 130.
Referring still to
During dispersant injection operations, dispersant is pumped from vessel 120 via pumps 122 down coiled tubing 124 to manifold assembly 140, which distributes the dispersant to one or more flying leads 190. Each flying lead 190 supplies dispersant to one application device 200. Thus, pumps 122 on vessel 120 facilitate the flow of dispersant through system 100 from storage tanks 121 to application devices 200.
One or more subsea ROVs 290 are employed to install the subsea components of system 100 and operate the subsea components of system 100 during dispersant injection operations. In this embodiment, each ROV 290 includes an arm 291 having a claw 292, a subsea camera 293 for viewing the subsea operations, and an umbilical 294. Streaming video and/or images from cameras 293 are communicated to the surface or other remote location via umbilical 294 for viewing on a live or periodic basis. Arms 291 and claws 292 are controlled via commands sent from the surface or other remote location to ROV 290 through umbilical 294. As will be described in more detail below, arms 291 and claws 292 enable ROVs 290 to grasp, manipulate, install, actuate, and position various subsea components.
Referring now to
In this embodiment, base 141 comprises a generally rectangular plate 142 mounted on a plurality of elongate, parallel joists 143 and a plurality of parallel cross-members 144 extending between adjacent joists 143. Plate 142 extends beyond the periphery of frame 150 and provides a relatively large surface area for engaging the sea floor 103. Consequently, base 141 functions as a “mud mat” that distributes the weight of manifold assembly 140 along the sea floor 103, thereby restricting and/or preventing manifold assembly 140 from sinking into the sea floor 103. As best shown in
Referring again to
In this embodiment, frame 150 includes four vertical posts 152, a first plurality of horizontal stringers or cross-members 153 extending between posts 152 at upper end 150a, and a second plurality of horizontal cross-members 153 extending between posts 152 at lower end 150b. Each post 152 is coaxially aligned with one post 147 of base 141 and is positioned at the intersection of one side 151a, b and one lateral side 151c, d. In addition, each post 152 has a first or upper end 152a disposed at frame upper end 150a, and a second or lower end 152b disposed at frame lower end 150b and releasably connected to one post 147 of base 141. In particular, each lower end 152b comprises a receptacle 154 that slidingly receives one extension 149, thereby coupling frame 150 to base 141. In this embodiment, one cross-member 153 extends perpendicularly between each pair of adjacent posts 152 at upper end 150a and lower end 150b, and one cross-member 153 extends between diagonally opposed posts 152 at upper end 150a an lower end 150b.
A plurality of handles 156 are coupled to posts 152 and cross-members 153. Handles 156 facilitate the grasping and manipulation of frame 150 at the surface and subsea. In this embodiment, each handle 156 is a generally U-shaped handle. Frame 150 also includes an umbilical connection plate 157 coupled to cross-members 152 at upper end 150a. Connection plate 157 includes a central, circular opening 158 that allows the inner lines and cables of a subsea umbilical to extend through plate 157 and into frame 150. As best shown in
Referring still to
Each arm 160 comprises a finger 163 rotatably coupled to free end 160b of each arm 160. More specifically, each finger 163 is pivotally coupled to one end 160b and configured to rotate about an axis 164 oriented perpendicular to distal portion 162 of the corresponding arm 160, perpendicular to a plane containing front side 151a, and parallel to plate 142. Each finger 163 coupled to each arm 160 connected to frame 150 at upper end 150a extends vertically upward from its corresponding end 160b, and each finger 163 coupled to each arm 160 connected to frame 150 at lower end 150b extends vertically downward from its corresponding end 160b. In addition, each finger 163 has a first position generally perpendicular to distal portion 162 of the corresponding arm 160 and plate 142, and a second position extending axially from distal portion 162 of the corresponding arm 160 and parallel to plate 142. Fingers 163 are biased to the first position, but may be transitioned to the second position by application of a force generally parallel to distal portion 162 of the corresponding arm 160 and perpendicular to a plane containing lateral side 151c.
As shown in
Dispersant manifold 170 is coupled to and supported by a dispersant control panel 171 positioned on front side 151a and extending between adjacent posts 152. In general, dispersant manifold 170 controls and routes the flow of dispersant pumped from vessel 120 through coiled tubing 124 to manifold assembly 140. As best shown in
Referring still to
In this embodiment, each valve 178 is a quarter-turn ball valve that is manually actuated by one or more subsea ROVs 290. However, in general, each valve 178 may comprise any suitable valve capable of being transitioned between an open position allowing fluid flow therethrough and a closed position preventing fluid flow therethrough. Examples of suitable valves include, without limitation, gate valves, ball valves, and butterfly valves. In addition, although valves 178 are manual valves operated by subsea ROVs 290 in this embodiment, in other embodiments, valves 178 may be actuated by other suitable means including, without limitation, hydraulically actuation, electrical actuation, pneumatic actuation, or combinations thereof. To minimize and/or eliminate the inadvertent emission of chemical dispersants into the surrounding sea water prior to venting or discharge of hydrocarbons subsea, valves 178 of outlets 174 are preferably closed until it is time to inject the dispersant into the subsea hydrocarbon stream. Inlet 172 and each outlet 174 also includes a pressure gauge 179 that measures the pressure of fluid within that particular inlet 172 and outlet 174, respectively.
As shown in
Referring now to
As best shown in
Referring still to
As shown in
Referring to
Referring now to
Device 200 also includes a dispersant inlet 202 and an inlet valve 203, each mounted to base 201. Inlet 202 in fluid communication with one flow line 190 previously described. In particular, inlet 202 is releasably connected to outlet end 190b of one flow line 190 with a coupling 192 as previously described. Inlet valve 203 controls the flow of dispersant through inlet 202 and wand 210. Specifically, when inlet valve 203 is opened, inlet 202 and flow line 190 are in fluid communication with wand 210. However, when valve 203 is closed, fluid communication between inlet 202 and wand 210 is restricted and/or prevented. In this embodiment, inlet valve 203 is a quarter-turn ball valve that is manually actuated by one or more subsea ROVs 290. However, in general, valve 203 may comprise any suitable valve capable of being transitioned between an open position allowing fluid flow therethrough and a closed position preventing fluid flow therethrough. Examples of suitable valves include, without limitation, gate valves, ball valves, and butterfly valves. In addition, although valve 203 is a manual valve operated by subsea ROVs 290 in this embodiment, in other embodiments, valve 203 may be actuated by other suitable means including, without limitation, hydraulic actuation, electrical actuation, pneumatic actuation, or combinations thereof. To minimize and/or eliminate the inadvertent emission of chemical dispersants into the surrounding sea water prior to venting or discharge of hydrocarbons subsea, valve 203 is preferably closed until it is time to inject the dispersant into the subsea hydrocarbon stream. In general, dispersant flows through flying lead 190 into inlet 202, and then through valve 203 to wand 210. For purposes of clarity, the flow lines connecting inlet 202 and valve 203, and wand 210 and valve 203 are not shown in
Referring now to
BOP 320 and LMRP 340 are configured to selectively seal wellbore 301 and contain hydrocarbon fluids therein with a plurality of sets of opposed rams 321 in BOP 320 (e.g., opposed blind shear rams or blades, opposed pipe rams, etc.) and/or an annular blowout preventer 341 in LMRP 340 (i.e., an annular elastomeric sealing element that is mechanically squeezed radially inward). During a “kick” or surge of formation fluid pressure in wellbore 301, one or more sets of rams 321 and/or annular BOP 341 are normally actuated to seal in wellbore 301. However, if the wellbore 301 is not sealed, a blowout may result. Such a blowout may compromise the ability to contain wellbore 301 and the hydrocarbon fluids therein. In
Referring now to
As shown in
Regardless of the geometry of the wand of the dispersant application device (e.g., straight wand 210, hook-shaped wand 330, C-shaped wand 340, Y-shaped wand 350, etc.), in embodiments, the dispersant nozzles may be positioned and oriented to generate a vortex to enhance mixing of the dispersant and the discharged hydrocarbons. In addition, the nozzles may also be configured to enhance the contact surface area between the discharged dispersant and the hydrocarbons. For example, the nozzles may be configured to discharge relatively small droplets of dispersant.
Referring now to
In this embodiment, the components of manifold assembly 140 (e.g., base 141, frame 150, arms 160, and panels 171, 181) shown in
Most conventional subsea manifolds are not sized and configured to be transported by air because their weight exceeds the payload capacity of conventional cargo aircraft and/or their dimensions cannot be accommodated by conventional aircraft cargo bays. Consequently, transport of such conventional manifolds is typically accomplished by land and/or sea vessel, which may be time consuming depending on the total transported distance. For example, if there is a subsea blowout in the Gulf of Mexico, and the most suitable manifold for routing dispersants subsea is located in the Middle East, it may take days or even weeks to transport the manifold by land and sea to the offshore location in the Gulf of Mexico. However, embodiments of dispersant manifold assemblies described herein (e.g., manifold assembly 140) are air-freightable, and thus, may be transported around the globe in a matter of hours or short number of days (e.g., 1-2 days maximum). As a result, embodiments described herein offer the potential to more efficiently and timely contain a subsea blowout, thereby potentially reducing the total volume of subsea hydrocarbon emissions.
Referring now to
Once manifold assembly 140 is sufficiently positioned on the sea floor 103, ROVs 290 are employed to facilitate the connection of dispersant flow line 124 to manifold inlet 172 (or to connect one or two umbilical dispersant line(s) to inlet(s) 173), the connection of inlet end 190a of each flying lead 190 to one outlet 174, the connection of outlet end 190b of each flying lead 190 to one dispersant application device 200, and the connection of any hydraulic fluid flow lines to manifold 180. Next, dispersants are pumped from vessel 120 to distribution system 130, and the appropriate valves 178 are manipulated (e.g., opened or closed) to direct the dispersants to application devices 200. Subsea ROVs 290 maneuver and manipulate devices 200 to inject chemical dispersants directly into stream 111 at discharge site 110.
As previously described, most conventional dispersant techniques rely on the application of dispersants to the relatively spread out oil slick at the sea surface. However, embodiments described herein enable the direct injection of chemical dispersants into the hydrocarbon stream at its subsea source. Without being limited by this or any particular theory, injecting dispersant at the point of subsea hydrocarbon release offers the potential to greatly improve dispersant efficiency, as compared to spreading dispersant over an oil slick on the surface of the sea, by maximizing mixing of the dispersant and hydrocarbons before substantial diffusion of the hydrocarbons. For example, it is believed that direct subsea application of dispersants prior to substantial mixing of oil and sea water may reduce the volume of dispersant necessary for effective oil dispersion by up to 70%. In addition, injecting dispersant at the point of subsea hydrocarbon release offers the potential to minimize VOCs at the surface, enhance microbial digestion/breakdown of the hydrocarbons subsea, and enable continuous 24 hour application of dispersants over a range of weather conditions and sea states. Further, direct injection into “fresh” oil at the discharge site reduces and/or eliminates problems associated with dispersant application to weathered crude oil.
It should be appreciated that embodiments described herein may be used in combination with other subsea dispersant injection systems such the subsea autonomous dispersant injection systems described in U.S. Patent Application Ser. No. 61/445,357, entitled “Subsea Autonomous Dispersant Injection System and Methods” filed Feb. 22, 2011, which is hereby incorporated herein by reference in its entirety for all purposes.
While preferred embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary only and are not limiting. Many variations and modifications of the systems, apparatus, and processes described herein are possible and are within the scope of the invention. For example, the relative dimensions of various parts, the materials from which the various parts are made, and other parameters can be varied. Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the steps in a method claim may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (1), (2), (3) before steps in a method claim are not intended to and do not specify a particular order to the steps, but rather are used to simplify subsequent reference to such steps.
Claims
1. A system for supplying a chemical dispersant to a subsea hydrocarbon discharge site, comprising:
- a surface vessel including a dispersant storage tank and a dispersant pump configured to pump dispersant from the storage tank;
- a first flow line coupled to the pump and extending subsea from the vessel;
- a subsea dispersant distribution system coupled to the first flow line;
- a dispersant injection device coupled to the distribution system and configured to inject dispersant from the tank into a subsea hydrocarbon stream.
2. The system of claim 1, wherein the subsea dispersant distribution system comprises:
- a subsea manifold assembly positioned at the sea floor, wherein the manifold assembly includes a base, a frame coupled to the base, and a chemical dispersant manifold coupled to the frame;
- wherein the chemical dispersant manifold includes a plurality of dispersant inlets and a plurality of dispersant outlets, wherein the first flow line is connected to one of the dispersant inlets; and
- a second flow line extending from one of the outlets of the chemical dispersant manifold to the injection device.
3. The system of claim 2, wherein each outlet of the chemical dispersant manifold includes a valve configured to control the flow of dispersant through the outlet; and
- wherein each inlet of the chemical dispersant manifold includes a valve configured to control the flow of dispersant through the inlet.
4. The system of claim 3, wherein at least a first of the inlets of the chemical dispersant manifold is configured to releasably connect with coiled tubing;
- wherein at least a second of the inlets of the chemical dispersant manifold is configured to releasably connect with an umbilical line.
5. The system of claim 4, wherein each outlet of the chemical dispersant manifold is configured to releasably connect with hot stab connector.
6. The system of claim 2, wherein the dispersant injection device includes a base and an elongate wand extending from the base;
- wherein the wand includes at least one nozzle configured to inject dispersant into the subsea hydrocarbon stream.
7. The system of claim 2, wherein the subsea manifold assembly comprises a plurality of arms connected to the frame, wherein a third flow line is wrapped around at least some of the plurality of arms.
8. The system of claim 2, wherein the subsea manifold assembly further comprises a hydraulic fluid manifold coupled to the frame;
- wherein the hydraulic fluid manifold includes a plurality of inlets and a plurality of outlets, each inlet of the hydraulic manifold coupled to one outlet of the hydraulic manifold with a hydraulic flow line;
- wherein each hydraulic flow line includes a valve configured to control the flow of hydraulic fluid through the hydraulic flow line.
9. The system of claim 1, wherein the base has a first weight and the frame has a second weight, wherein the sum of the first weight and the second weight is less than 120 tons.
10. The system of claim 1, wherein the base and the frame are each configured to be air freightable.
11. A method for responding to a subsea hydrocarbon discharge at an offshore location, comprising:
- (a) storing a subsea manifold assembly, a flying lead, and a dispersant application device together at a common location;
- (b) transporting the manifold assembly, the flying lead, and the application device to the offshore location;
- (c) lowering the manifold assembly subsea after (b).
12. The method of claim 11, further comprising:
- (d) connecting a first end of the flying lead to an outlet of the dispersant manifold after (c); and
- (e) connecting a second end of the flying lead to an inlet of the application device after (c).
13. The method of claim 12, further comprising:
- (f) connecting a lower end of a dispersant flow line to an inlet of the dispersant manifold after (c).
14. The method of claim 13, wherein (d), (e, and (f) are performed with one or more subsea ROVs.
15. The method of claim 13, further comprising:
- (g) flowing a chemical dispersant from a surface vessel through the dispersant flow line to the dispersant manifold;
- (h) flowing the chemical dispersant from the dispersant manifold through the flying lead to the application device.
16. The method of claim 15, further comprising:
- (i) injecting the chemical dispersant into a stream of hydrocarbons emitted at a source of the hydrocarbon discharge.
17. The method of claim 13, wherein (b) comprises transporting the manifold assembly, the flying lead, and the application device by air.
18. The method of claim 13, wherein (a) further comprises storing a plurality of flying leads, a plurality of dispersant application devices, and a plurality of tools together at the common location.
19. The method of claim 18, wherein the plurality of tools comprise ROV operated tools for clearing debris subsea selected from the group consisting of saws, grinders, and diamond wires.
20. The method of claim 11, further comprising:
- storing a chemical dispersant in a storage tank at the sea surface;
- pumping the chemical dispersant from the storage tank through a dispersant flow line to the dispersant manifold.
Type: Application
Filed: Jun 26, 2012
Publication Date: Jan 24, 2013
Applicant: BP CORPORATION NORTH AMERICA INC. (Houston, TX)
Inventor: Keith Magowan (Surrey)
Application Number: 13/533,538
International Classification: E02B 15/04 (20060101); E21B 41/00 (20060101);