US20130140035A1 - Systems And Methods For Collecting Hydrocarbons Vented From A Subsea Discharge Site - Google Patents
Systems And Methods For Collecting Hydrocarbons Vented From A Subsea Discharge Site Download PDFInfo
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- US20130140035A1 US20130140035A1 US13/673,365 US201213673365A US2013140035A1 US 20130140035 A1 US20130140035 A1 US 20130140035A1 US 201213673365 A US201213673365 A US 201213673365A US 2013140035 A1 US2013140035 A1 US 2013140035A1
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- subsea
- overshot tool
- connection member
- control device
- pressure control
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/0122—Collecting oil or the like from a submerged leakage
Definitions
- the invention relates generally to systems and methods for collecting hydrocarbons vented from a subsea discharge site. More particularly, the invention relates to systems and methods for collecting the bulk hydrocarbon flow from a pre-determined, controlled subsea pressure exhaust vent point.
- a blowout preventer BOP
- LMRP lower marine riser package
- 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.
- a choke line and a kill line are also suspended from the rig and coupled to the BOP, usually as part of the drilling riser assembly.
- drilling fluid or mud
- drilling fluid is delivered through the drill string, and returned up an annulus between the drill string and casing that lines the well bore.
- the BOP and/or LMRP may actuate to seal the annulus and control the well.
- BOPs and LMRPs comprise closure members capable of sealing and closing the well in order to prevent the release of high-pressure gas and/or liquids from the well.
- the BOP and LMRP are used as safety devices that close, isolate, and seal the wellbore.
- Heavier drilling mud may be delivered through the drill string, forcing fluid from the annulus through the choke line or kill line to protect the well equipment disposed above the BOP and LMRP from the high pressures associated with the formation fluid. Assuming the structural integrity of the well has not been compromised, drilling operations may resume. However, if drilling operations cannot be resumed, cement or heavier drilling mud is delivered into the well bore to kill the well.
- a fluid conduit e.g., choke line
- a subsea blowout may damage the subsea BOP, LMRP, or riser, potentially resulting in the discharge of hydrocarbons into the surrounding sea.
- capping stack subsea One approach to capping and shutting-in the subsea well is to lower a capping stack subsea, couple the capping stack to the upper end of the subsea BOP or LMRP that is discharging hydrocarbons, and then utilize the capping stack to shut-in the well.
- Examples of capping stacks, methods of deploying and installing capping stacks, and methods of containing a subsea well with capping stacks are described in U.S. Patent Application Ser. No. 61/475,032 filed Apr. 13, 2011 and entitled “Systems and Methods for Capping a Subsea Well,” which is hereby incorporated herein by reference in its entirety for all purposes.
- hydrocarbon fluids may be controllably vented from the well through the capping stack into the surrounding sea.
- a sudden and potentially prolonged release of hydrocarbon fluids at a subsea discharge site may result from the shut-in of a surface flow containment vessel during a cap and flow response operation.
- a normally closed discharge site protected by a pressure safety valve or burst disc assembly may open in response to a shut-in and associated wellbore pressure increase.
- a choke outlet on a capping stack mounted to a subsea BOP may be allowed to vent hydrocarbons subsea during a relief well bottom-kill operation.
- hydrocarbon fluids discharged into the sea are allowed to rise to the surface, where they are treated with chemical dispersing agents, which 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.
- dispersants are sprayed onto the oil at the surface of the water.
- oil at the surface is often spread out over a relatively large area (e.g., hundreds or thousands of square miles).
- relatively large quantities of dispersant must be distributed over the relatively large area encompassed by the oil slick.
- 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).
- turbulence at the surface e.g., wave action
- surface turbulence may be less than adequate.
- the method comprises (a) mounting a pressure control device to the subsea discharge site. Further, the method comprises (b) flowing the vented hydrocarbon fluids from the subsea discharge site through the pressure control device. Still further, the method comprises (c) positioning a collection system subsea on a lower end of a tubular string. Moreover, the method comprises (d) flowing the vented hydrocarbons fluids from the pressure control device into the collection system and through the tubular string after (b). The method also comprises (e) minimizing lateral loads applied to the subsea discharge site by the collection system.
- the assembly comprises a collection system including a connection member, an overshot tool, and a flexible conduit extending from the overshot tool to the connection member.
- the connection member has a central axis, an upper end, a lower end, and a flow passage extending axially from the upper end to the lower end, the upper end configured to releasably connect to a lower end of a tubular string and the lower end coupled to the flexible conduit.
- the overshot tool has a central axis, an upper end coupled to the flexible conduit, a lower end, and a flow passage extending from the lower end of the overshot tool to the upper end of the overshot tool.
- the overshot tool includes an elongate slot extending axially from the lower end and extending radially through the overshot tool to the flow passage of the overshot tool.
- the flexible conduit is in fluid communication with the flow passage of the overshot tool and the flow passage of the connection member.
- the assembly comprises a collection system including a connection member and an overshot tool.
- the connection member has a central axis, an upper end, a lower end, and a flow passage extending axially from the upper end to the lower end, the upper end configured to releasably connect to a lower end of a tubular string and the lower end comprising a funnel guide.
- the overshot tool has a central axis, an upper end, a lower end, a flow passage extending from the lower end of the overshot tool to the upper end of the overshot tool.
- the overshot tool includes a coupling member at the lower end of the overshot tool and an elongate stabbing member extending axially from the coupling member to the upper end of the overshot tool.
- the stabbing member is slidingly disposed in the flow passage of the connection member.
- Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods.
- the foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood.
- 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. It should be appreciated by those skilled in the art that the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
- FIG. 1 is a schematic view of an embodiment of an offshore drilling system
- FIG. 2 is a schematic view of the offshore drilling system of FIG. 1 damaged by a subsea blowout;
- FIG. 3 is a schematic front view of an embodiment of a capping stack mounted to the BOP of FIG. 2 ;
- FIG. 4 is an enlarged schematic front view of the capping stack of FIG. 3 ;
- FIG. 5 is an enlarged schematic side view of the capping stack of FIG. 3 ;
- FIG. 6 is a partial cut-away side view of an embodiment of a subsea pressure control device for connecting to one of the side outlets of the capping stack of FIG. 3 ;
- FIG. 7 is a front view of the pressure control device of FIG. 6 ;
- FIGS. 8-11 are sequential schematic views of the deployment and installation of the pressure control device of FIG. 6 onto the capping stack of FIG. 3 ;
- FIG. 12 is a side view of an embodiment of a collection apparatus for capturing hydrocarbon fluids exhausted from a subsea discharge site
- FIG. 13 is an enlarged view of the connection member of FIG. 12 ;
- FIG. 14 is an enlarged view of the overshot tool of FIG. 12 ;
- FIGS. 15-17 are sequential schematic views illustrating the collection apparatus of FIG. 12 being deployed subsea and positioned to collect hydrocarbons discharged from the pressure control device of FIG. 11 ;
- FIG. 18 is a side view of an embodiment of a collection assembly for capturing hydrocarbon fluids exhausted from a subsea discharge site
- FIG. 19 is an enlarged view of the connection member of FIG. 18 ;
- FIG. 20 is an enlarged view of the overshot tool of FIG. 18 ;
- FIGS. 21-26 are sequential views illustrating the collection assembly of FIG. 17 being deployed subsea and positioned to collect hydrocarbons discharged from the pressure control device of FIG. 11 ;
- FIG. 27 is a front view of an embodiment of a collection apparatus for capturing hydrocarbon fluids exhausted from a subsea discharge site.
- FIGS. 28-30 are sequential views illustrating the collection apparatus of FIG. 27 being deployed subsea and positioned to collect hydrocarbons discharged from the pressure control device of FIG. 11 .
- the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .”
- 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.
- 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.
- system 100 includes an offshore platform or mobile offshore drilling unit (MODU) 110 at the sea surface 102 , a subsea blowout preventer (BOP) 120 mounted to a wellhead 130 at the sea floor 103 , and a lower marine riser package (LMRP) 140 attached to BOP 120 .
- Platform 110 is equipped with a derrick 111 that supports a hoist (not shown).
- a drilling riser 115 extends from platform 110 to LMRP 140 .
- riser 115 is a large-diameter pipe that connects LMRP 140 to the MODU 110 .
- riser 115 takes mud returns to the MODU 110 .
- Casing 131 extends from wellhead 130 into subterranean wellbore 101 .
- Downhole operations are carried out by a tubular string 116 (e.g., drillstring, production tubing string, coiled tubing, etc.) that is supported by derrick 111 and extends from MODU 110 through riser 115 , LMRP 140 , BOP 120 , and into cased wellbore 101 .
- a downhole tool 117 is connected to the lower end of tubular string 116 .
- downhole tool 117 may comprise any suitable downhole tool(s) for drilling, completing, evaluating and/or producing wellbore 101 including, without limitation, drill bits, packers, testing equipment, perforating guns, and like.
- string 116 and hence tool 117 coupled thereto, may move axially, radially, and/or rotationally relative to riser 115 , LMRP 140 , BOP 120 , and casing 131 .
- BOP 120 and LMRP 140 are configured to controllably seal wellbore 101 and contain hydrocarbon fluids therein.
- BOP 120 has a central or longitudinal axis 125 and includes a body 123 with an upper end releasably secured to LMRP 140 , a lower end releasably secured to wellhead 130 , and a main bore 124 extending axially between the upper and lower ends.
- Main bore 124 is coaxially aligned with wellbore 101 , thereby allowing fluid communication between wellbore 101 and main bore 124 .
- BOP 120 is releasably coupled to LMRP 140 and wellhead 130 with hydraulically actuated, mechanical wellhead-type connectors 150 .
- connectors 150 may comprise any suitable releasable wellhead-type mechanical connector such as the H-4® profile subsea connector available from VetcoGray Inc. of Houston, Tex. or the DWHC profile subsea connector available from Cameron International Corporation of Houston, Tex.
- wellhead-type mechanical connectors e.g., connectors 150
- such wellhead-type mechanical connectors comprise a male component or coupling that is inserted into and releasably locked within a mating female component or coupling.
- BOP 120 includes a plurality of axially stacked sets of opposed rams—opposed blind shear rams or blades 127 for severing tubular string 116 and sealing off wellbore 101 from riser 115 , opposed blind rams 128 for sealing off wellbore 101 when no string (e.g., string 116 ) or tubular extends through main bore 124 , and opposed pipe rams 129 for engaging string 116 and sealing the annulus around tubular string 116 .
- Each set of rams 127 , 128 , 129 is equipped with sealing members that engage to prohibit flow through the annulus around string 116 and/or main bore 124 when rams 127 , 128 , 129 is closed.
- Opposed rams 127 , 128 , 129 are disposed in cavities that intersect main bore 124 and support rams 127 , 128 , 129 as they move into and out of main bore 124 .
- Each set of rams 127 , 128 , 129 is actuated and transitioned between an open position and a closed position. In the open positions, rams 127 , 128 , 129 are radially withdrawn from main bore 124 and do not interfere with tubular string 116 or other hardware that may extend through main bore 124 .
- rams 127 , 128 , 129 are radially advanced into main bore 124 to close off and seal main bore 124 (e.g., rams 127 , 128 ) or the annulus around tubular string 116 (e.g., rams 129 ).
- Each set of rams 127 , 128 , 129 is actuated and transitioned between the open and closed positions by a pair of actuators 126 .
- each actuator 126 hydraulically moves a piston within a cylinder to move a drive rod coupled to one ram 127 , 128 , 129 .
- LMRP 140 has a body 141 with an upper end connected to the lower end of riser 115 , a lower end releasably secured to BOP 120 with connector 150 , and a throughbore 142 extending axially between the upper and lower ends.
- Throughbore 142 is coaxially aligned with main bore 124 of BOP 120 , thereby allowing fluid communication between throughbore 142 and main bore 124 .
- LMRP 140 also includes an annular blowout preventer 142 a comprising an annular elastomeric sealing element that is mechanically squeezed radially inward to seal on a tubular extending through bore 142 (e.g., string 116 , casing, drillpipe, drill collar, etc.) or seal off bore 142 .
- annular BOP 142 a has the ability to seal on a variety of pipe sizes and seal off bore 142 when no tubular is extending therethrough.
- the upper end of LMRP 140 comprises a riser flex joint 143 that allows riser 115 to deflect angularly relative to BOP 120 and LMRP 140 while hydrocarbon fluids flow from wellbore 101 , BOP 120 and LMRP 140 into riser 115 .
- Flex joint 143 includes a riser adapter 145 with an annular flange 145 a at its upper end for coupling to a mating annular flange 118 at the lower end of riser 115 or to alternative devices.
- LMRP 140 has been shown and described as including a particular flex joint 143 , in general, any suitable riser flex joint may be employed in LMRP 140 .
- BOP 120 includes three sets of rams (one set of shear rams 127 , one set of pipe rams 129 , and one blind rams 128 ), however, in other embodiments, the BOP (e.g., BOP 120 ) may include a different number of rams (e.g., four sets of rams), different types of rams (e.g., two sets of shear rams and one set of pipe rams), an annular BOP (e.g., annular BOP 142 a ), or combinations thereof.
- a different number of rams e.g., four sets of rams
- different types of rams e.g., two sets of shear rams and one set of pipe rams
- annular BOP e.g., annular BOP 142 a
- LMRP 140 is shown and described as including one annular BOP 142 a, in other embodiments, the LMRP (e.g., LMRP 140 ) may include a different number of annular BOPs (e.g., two sets of annular BOPs), different types of rams (e.g., shear rams), or combinations thereof.
- FIG. 2 during a “kick” or surge of formation fluid pressure in wellbore 101 , resulting in a blowout, potentially resulting in the discharge of such hydrocarbon fluids subsea in the form of a plume 160 that extends to the sea surface 102 .
- system 100 is shown after a subsea blowout.
- a capping stack may be deployed subsea and installed onto BOP 120 as described in U.S. Patent Application Ser. No. 61/475,032 filed Apr. 13, 2011 and entitled “Systems and Methods for Capping a Subsea Well,” which is hereby incorporated herein by reference in its entirety for all purposes.
- capping stack 200 for capping and controlling wellbore 101 previously described ( FIG. 2 ) is shown.
- capping stack 200 comprises a drilling BOP 210 similar to BOP 120 previously described.
- BOP 210 has a central or longitudinal axis 215 , and includes a body 212 with a first or upper end 212 a, a second or lower end 212 b, and a main bore 213 extending axially between ends 212 a, b .
- Upper end 212 a comprises a male coupling of a wellhead-type connector 150 and lower end 212 b comprises the female coupling of a wellhead-type connector 150 .
- BOP 210 includes a plurality of axially stacked sets of opposed rams—one set of opposed blind shear rams or blades 127 , one set of opposed blind rams 128 , and one set of opposed pipe rams 129 , each as previously described.
- Opposed rams 127 , 128 , 129 are disposed in cavities that intersect main bore 213 and support rams 127 , 128 , 129 as they move into and out of main bore 213 .
- Each set of rams 127 , 128 , 129 is actuated and transitioned between an open position and a closed position.
- rams 127 , 128 , 129 are radially withdrawn from main bore 213
- rams 127 , 128 , 129 are radially advanced into main bore 213 to close off and seal main bore 213
- Each set of rams 127 , 128 , 129 is actuated and transitioned between the open and closed positions by a pair of actuators 126 as previously described.
- a plurality of T-handles 219 extend radially outward from body 212 , and enable ROVs to manipulate, rotate, and position stack 200 during subsea deployment.
- stack 200 also includes a plurality of side outlets 214 extending from main bore 213 through body 212 .
- Each side outlet 214 has a first end 214 a in fluid communication with main bore 213 , a second end 214 b distal main bore 213 and extending from body 212 , and an isolation valve 214 c that controls the flow of fluids through the side outlet 214 .
- Side outlets 214 provide a means for relieving the pressure of fluids in main bore 213 .
- each side outlet 214 comprises an upward facing male component or coupling 216 that is received by and releasably locked within a mating female component or coupling.
- pressure control device 300 is a choke assembly having a central axis 305 , a first or upper end 300 a, and a second or lower end 300 b opposite end 300 a.
- choke assembly 300 includes an annular receiving guide 310 at lower end 300 b , a downward facing female component or coupling 320 axially adjacent guide 310 , a choke valve 330 at upper end 300 a, and a tubular fluid conduit 340 extending axially between coupling 320 and choke valve 330 .
- Receiving guide 310 includes an inner passage 311 extending axially from lower end 300 b to coupling 320 .
- passage 311 comprises an inverted frustoconical guide surface 312 configured to receive and guide second end 214 b of side outlet 214 into coupling 320 .
- a pair of handles 313 extend radially outward from guide 310 and enable ROVs to manipulate, rotate, and position device 300 during subsea deployment.
- Female coupling 320 is configured to matingly receive and releasably lock onto coupling 216 of side outlet 214 , thereby securing choke assembly 300 to side outlet 214 .
- coupling 320 is a hydraulically actuated, mechanical connector that releasably locks onto and sealingly engages coupling 216 . More specifically, when coupling 216 at end 214 b of side outlet 214 is sufficiently seated within connector 320 , connector 320 is hydraulically actuated to releasably lock onto end 214 b .
- couplings 216 , 320 may comprises any suitable types of connectors known in the art for forming a secure, releasably connection between side outlet 214 and choke assembly 300 .
- Suitable types of couplings include, without limitation, three inch Choke and Kill Connector available from Cameron international Corporation of Houston, Tex.; the Optima Subsea Connector available from Vector Group, Inc. of Houston, Tex.; and the RIC and RAC connectors available from Oil States international, Inc. of Arlington, Tex.
- choke valve 330 has an inlet 331 , an outlet 332 , and is configured to choke the flow of fluids through pressure control device 300 .
- a tubular exhaust conduit 335 attached to choke valve 330 has a lower inlet end 335 a in fluid communication with outlet 332 and an open, upper outlet end 336 b opposite end 335 a.
- Conduit 340 extends from coupling 320 to choke valve 330 and provides fluid communication between coupling 320 and inlet 331 .
- conduit 335 includes a 90° bend between ends 335 a, b that allows inlet end 335 a to be oriented perpendicular to axis 305 and outlet end 335 b to be oriented parallel to axis 305 .
- pressure control device 300 also includes an ROV control panel 350 that enables a subsea ROV to operate choke valve 330 , as well as operate the other functions of device 300 .
- device 300 includes a hydraulic fluid control valve 351 a , a test fluid control valve 352 a, a chemical injection control valve 353 a, and a chemical dispersant control valve 354 a.
- Each valve 351 a, 352 a, 353 a, 354 a is mounted to control panel 350 and is accessed and controlled subsea with an ROV via an associated valve actuation member 351 b , 352 b, 353 b, 354 b, respectively, disposed on control panel 350 .
- Each valve 351 a , 352 a, 353 a, 354 a has an inlet coupled to a fluid inlet supply line and an outlet coupled to a fluid outlet supply line.
- the inlet supply lines and the outlet supply lines are not shown in FIGS. 6 and 7 .
- the inlet of valve 351 a is connected to a pressurized hydraulic fluid supply line
- inlet of valve 352 a is connected to a test fluid supply line
- the inlet of valve 353 a is connected to a chemical injection supply line
- an inlet of valve 354 a is connected to a chemical dispersant supply line.
- valve 351 a selectively supplies pressurized hydraulic fluid to connector 320 to actuate connector 320 between the locked and unlocked positions; the outlet of valve 352 a selectively supplies testing fluids (e.g., glycol, methanol, etc.) to device 300 proximal choke valve inlet 331 ; the outlet of valve 353 a selectively supplies chemicals (e.g., methanol) to inlet end 335 a of exhaust conduit 335 ; and the outlet of valve 354 a selectively supplies dispersant (e.g., Corexit® EC9500A available from Nalco Company of Naperville, Ill.) to conduit 335 between ends 335 a, b .
- a choke valve actuator member 355 is positioned axially above control panel 350 and allows a subsea ROV to actuate choke valve 330 .
- pressure control device 300 is shown being deployed and installed subsea on end 214 b of one side outlet 214 to choke and control the flow of hydrocarbons exhausted from capping stack 200 . More specifically, in FIG. 8 , device 300 is shown being lowered subsea; in FIG. 9 , device 300 is shown being moved laterally over end 214 b of one side outlet 214 ; in FIG. 10 , device 300 is shown being generally coaxially aligned with end 214 b and lowered into engagement with side outlet 214 ; and in FIG. 11 , device 300 is shown being secured to end 214 b of side outlet 214 .
- the side outlet 214 to which device 300 is mounted (the side outlet 214 shown on the right in FIGS. 8-11 ) is designated with reference numeral 214 ′ to distinguish it from the other side outlet 214 (the side outlet 214 shown on the left in FIGS. 8-11 ), which is designated with reference numeral 214 ′′.
- valve 214 c associated with the side outlet 214 ′ is preferably closed prior to and during installation of device 300 .
- valve 214 c associated with the other side outlet 214 ′′ is preferably open prior to and during installation of device 300 .
- FIGS. 1-10 In the exemplary installation sequence shown in FIGS.
- valve 214 c of the side outlet 214 ′ is closed prior to and during installation of device 300
- valve 214 c of side outlet 214 ′′ is open prior to and during installation of device 300
- main bore 213 is closed downstream of ends 214 a (e.g., one or more rams 127 , 128 , 129 are closed) prior to, during, and after installation of device 300 .
- valve 214 c of side outlet 214 ′ is opened, valve 214 c of side outlet 214 ′′ is closed, main bore 213 remains closed, and device 300 is employed. to choke the flow through side outlet 214 ′.
- ROVs remote operated vehicles
- one or more remote operated vehicles are preferably employed to aid in positioning device 300 , monitoring device 300 , BOP 120 , and capping stack 200 , and selectively actuating valves 330 , 351 a, 352 a, 353 a , 354 a.
- two ROVs 170 are provided to facilitate the installation and operation of device 300 as well as monitor device 300 and BOPs 120 , 210 .
- Each ROV 170 includes an arm 171 having a claw 172 , a subsea camera 173 for viewing the subsea operations (e.g., the relative positions of stack 200 and device 300 , plume 160 , the positions and movement of arms 170 and claws 172 , etc.), and an umbilical 174 .
- Streaming video and/or images from cameras 173 are communicated to the surface or other remote location via umbilical 174 for viewing on a live or periodic basis.
- Arms 171 and claws 172 are controlled via commands sent from the surface or other remote location to ROV 170 through umbilical 174 .
- device 300 is shown being controllably lowered subsea with a plurality of wireline cables 180 secured to device 300 and extending to a surface vessel.
- a winch or crane mounted to a surface vessel is preferably employed to support and lower device 300 on cables 180 .
- device 300 is lowered subsea under its own weight from a location generally above and laterally offset from wellbore 101 and capping stack 200 . More specifically, during deployment, device 300 is preferably maintained outside of plume 160 of hydrocarbon fluids emitted from cap 200 . Lowering device 300 subsea in plume 160 may trigger the undesirable formation of hydrates within device 300 , particularly at elevations substantially above sea floor 103 where the temperature of hydrocarbons in plume 160 is relatively low.
- device 300 is lowered laterally offset from stack 200 and outside of plume 160 until guide 310 is slightly above end 214 b of closed side outlet 214 ′.
- ROVs 170 monitor the position of device 300 relative to capping stack 200 .
- device 300 is moved laterally into position immediately above end 214 b of side outlet 214 ′ with guide 310 substantially coaxially aligned with end 214 b.
- One or more ROVs 170 may utilize their claws 172 and handles 313 to guide and rotate device 300 into proper alignment relative to end 214 b.
- cables 180 lower device 300 axially downward, thereby inserting and axially advancing end 214 b of side outlet 214 ′ into guide 310 and coupling 320 until end 214 b is sufficiently seated in coupling 320 .
- the frustoconical guide surface 312 at lower end 300 b functions to guide end 214 b into coupling 320 , even if end 214 b is initially slightly misaligned with guide 310 .
- choke valve 330 Prior to moving device 300 laterally over side outlet 214 ′, is preferably transitioned to the open position.
- Choke valve 330 may be transitioned to the open position at the surface 102 prior to deployment, or subsea via one or more ROVs 170 . Since outlet 214 ′ was previously closed, there is little to no resistance to the axial insertion of end 214 b into guide 310 and coupling 320 .
- an ROV 170 actuates coupling 320 to lock onto mating coupling 216 at end 214 b, thereby securing device 300 onto side outlet 214 ′.
- cables 180 may be decoupled from stack 200 with ROVs 170 and removed to the surface.
- valve 214 c of side outlet 214 ′ is opened, thereby allowing emitted hydrocarbon fluid to flow freely through outlets 214 ′, 214 ′′ and device 300 .
- valve 214 c of outlet 214 ′′ is closed, and choke valve 330 may be adjusted (e.g., transitioned to a partially closed position) with an ROV 170 to achieve the desired pressure and flow through side outlet 214 ′.
- choke valve 330 may be adjusted (e.g., transitioned to a partially closed position) with an ROV 170 to achieve the desired pressure and flow through side outlet 214 ′.
- Any such vented hydrocarbon fluids from device 300 or other subsea structure e.g., subsea manifold
- Embodiments of system and methods for capturing and collecting hydrocarbons vented from device 300 following connection of device 300 to side outlet 214 ′ are described in more detail below.
- System 400 for capturing hydrocarbon fluids exhausted from a subsea discharge site (e.g., hydrocarbons discharged from exhaust conduit 335 ) is shown.
- System 400 has a central or longitudinal axis 405 , a first or upper end 400 a, and a second or lower end 400 b opposite end 400 a.
- system 400 includes a connection member 410 at upper end 400 a, an overshot tool 420 at lower end 400 b, and a flexible conduit 430 extending from connection member 410 to overshot tool 420 .
- Connection member 410 , tool 420 , and flexible conduit 430 are connected end-to-end with connectors 440 .
- connection member 410 has a central axis 415 coincident with axis 405 , a first or upper end 410 a defining upper end 400 a of system 400 , a second or lower end 410 b coupled to conduit 430 with connector 440 , and a central through bore 411 extending axially between ends 410 a, b .
- connection member 410 includes a J-latch coupling 412 extending axially from upper end 410 a, an elongate pipe 413 extending axially from lower end 410 b to J-latch coupling 412 , and an ROV control panel 414 attached to pipe 413 .
- ROV control panel 414 is disposed along pipe 413 axially below latch coupling 412 and includes a stabbing port for injecting a hydrate inhibitor (e.g., methanol) into pipe 413 to reduce and/or prevent the formation of hydrates downstream of pipe 413 .
- a hydrate inhibitor e.g., methanol
- J-latch coupling 412 comprises a rigid tubular body 416 having an annular funnel guide 417 at upper end 410 a and a pair of circumferentially spaced J-slots 418 positioned axially adjacent guide 417 .
- J-slots 418 are angularly spaced 180° apart relative to axis 415 .
- a J-slot defines a track on a first device that releasably receives a mating pin on a second device to releasably couple the first and second devices.
- a J-slot connection is capable of transferring tensile and compression axial loads, as well as rotational torque.
- each J-slot 418 extends radially through body 416 to bore 411 and is configured to slidingly receive a pin on the lower end of a tubular string (e.g., drillstring) to releasably couple connection member 410 and system 400 to the tubular string for subsea deployment and manipulation.
- a tubular string e.g., drillstring
- overshot tool 420 has a central axis 425 coincident with axis 405 , a first or upper end 420 a coupled to conduit 430 with one connector 440 , a second or lower end 420 b defining end 400 b of system 400 , and a central through bore 421 extending axially between ends 420 a, b .
- overshot tool 420 comprises a rigid tubular body 422 having an elongate slot 423 extending axially from lower end 420 b and extending radially through body 422 to bore 421 .
- Slot 423 defines opposed lateral edges 424 .
- a resilient rubber bumper 426 is mounted to each edge 424 proximal the upper end of slot 423 .
- bumpers 426 provide a resilient, flexible surface configured to slidingly engage conduit 335 of pressure control device 300 when system 400 is mounted thereto.
- Overshot tool 420 also includes a pair of handles 427 that extend radially outward from body 422 and enable ROVs to manipulate, rotate, and position system 400 during subsea deployment.
- hydrocarbon collection system 400 is shown being deployed subsea and positioned to capture hydrocarbons discharged from exhaust conduit 335 . More specifically, in FIG. 15 , system 400 is shown being lowered subsea; in FIG. 16 , system 400 is shown being moved laterally over outlet end 335 b of exhaust conduit 335 ; and in FIG. 17 , system 400 is shown being advanced over outlet end 335 b of exhaust conduit 335 to capture hydrocarbons emitted therefrom.
- one or more ROVs 170 are preferably employed to aid in positioning collection system 400 and monitoring collection system 400 , pressure control device 300 , BOPs 120 , and capping stack 200 .
- system 400 is coupled to the lower end of a tubular string 700 at the surface 102 with J-latch coupling 412 , and is then controllably lowered subsea with string 700 .
- a derrick or other suitable device mounted to a surface vessel is preferably employed to support and lower system 400 on string 700 .
- system 400 is lowered subsea from a location generally above and laterally offset from exhaust conduit 335 . More specifically, during deployment, system 400 is preferably maintained outside of plume 160 of hydrocarbon fluids emitted from exhaust conduit 335 . Lowering system 400 subsea in plume 160 may trigger the undesirable formation of hydrates within system 400 and/or string 700 , particularly at elevations substantially above sea floor 103 where the temperature of hydrocarbons in plume 160 is relatively low.
- a hydrate inhibitor e.g., methanol
- string 700 can be filled with an inert gas such as nitrogen to help prevent the formation of hydrates therein during installation of system 400 .
- system 400 is lowered laterally offset from exhaust conduit 335 and outside of plume 160 until overshot tool 420 is slightly above outlet end 335 b.
- ROVs 170 monitor the position of system 400 relative to capping stack 200 and device 300 .
- system 400 is rotated and oriented to circumferentially align conduit 335 with slot 423 .
- system 400 is moved laterally into position immediately above end 335 b with tool 420 substantially coaxially aligned with end 335 b .
- One or more ROVs 170 may utilize their claws 172 and handles 427 to guide and rotate system 400 into proper alignment relative to exhaust conduit 335 .
- hydrocarbon fluids discharged from exhaust conduit 335 flow upward through system 400 and string 700 to the surface where they may be captured and contained.
- a hydrate inhibitor e.g., methanol
- a hydrate inhibitor may be injected into pipe 413 via control panel 414 while system 400 is being lowered over the exhaust and/or during collection of discharged hydrocarbons to prevent and/or reduce the formation of hydrates within J-latch coupling 412 and string 700 .
- the weight of system 400 is supported by string 700 to minimize the transfer of any loads to exhaust conduit 335 and pressure control device 300 .
- Minimizing loads on exhaust conduit 335 as well as the flexibility of conduit 430 of collection system 400 offers the potential to reduce the chances of inadvertently damaging conduit 335 and/or control device 300 , particularly if the deployment vessel at the surface 102 experiences a sudden lateral or vertical movement.
- system 500 for capturing hydrocarbon fluids exhausted from a subsea discharge site (e.g., hydrocarbons discharged from exhaust conduit 335 ) is shown.
- system 500 includes a connection member 510 and an overshot tool 520 .
- Connection member 510 is hung from the lower end of a tubular string (e.g., string 700 ), and overshot tool 520 is coupled to the discharge site and is slidingly received by the connection member 510 subsea.
- connection member 510 has a central axis 515 , a first or upper end 510 a, a second or lower end 510 b opposite end 510 a, and a central through passage 511 extending axially between ends 510 a, b .
- connection member 510 includes a J-latch coupling 412 as previously described extending axially from upper end 510 a and an elongate pipe 513 extending axially from lower end 510 b to J-latch coupling 412 .
- J-latch coupling 412 comprises a rigid tubular body 416 having an annular funnel guide 417 at upper end 410 a and a pair of circumferentially spaced J-slots 418 positioned axially adjacent guide 417 .
- Each J-slot 418 extends radially through body 416 to passage 511 and is configured to slidingly receive a pin on the lower end of a tubular string (e.g., drillstring) to releasably couple connection member 510 to the tubular string for subsea deployment and manipulation
- Pipe 513 comprises a rigid tubular body 514 having a generally rectangular funnel guide 516 at lower end 510 b and a pair of handles 517 axially adjacent guide 516 .
- Handles 517 extend radially outward from body 514 and enable ROVs to manipulate, rotate, and position connection member 510 during subsea deployment.
- the upper end of pipe 513 is coupled to the lower end of J-latch coupling 412 with a flex joint 518 that allows pipe 513 to pivot relative to J-latch coupling 412 .
- An ROV control panel (e.g., ROV control panel 414 ) may be disposed along pipe 513 axially below J-latch coupling 512 for injecting a hydrate inhibitors (e.g., methanol) into pipe 513 to reduce and/or prevent the formation of hydrates downstream of pipe 513 .
- a hydrate inhibitors e.g., methanol
- overshot tool 520 has a central axis 525 , a first or upper end 520 a, a second or lower end 520 b opposite end 520 a, and a central through bore 521 extending axially between ends 520 a, b .
- overshot tool 520 includes a coupling member 522 at lower end 520 b and an elongate stabbing member 523 extending from coupling member 522 to upper end 520 a.
- a flex joint e.g., flex joint 518
- Coupling member 522 comprises a rigid tubular body 523 , a handle 524 , and a plurality of circumferentially spaced locking members 526 .
- Handle 524 extends radially outward from body 523 and enables ROVs to manipulate, rotate, and position overshot tool 520 during subsea deployment.
- Locking members 526 releasably secure overshot tool 520 to the hydrocarbon discharge site (e.g., end 335 b of exhaust conduit 335 ).
- the hydrocarbon discharge site e.g., end 335 b of exhaust conduit 335
- three locking members 526 uniformly spaced 90° apart are provided.
- each locking member 526 is a T-bolt that threadingly engages a mating bore extending radially through body 523 .
- each locking member 526 has a first or radially outer end 526 a disposed outside body 523 and a second or radially inner end (not shown) extending into bore 521 .
- End 526 a of each locking member 526 is a T-handle that enables an ROV to rotate the corresponding locking member 526 to thread it radially inward and outward through body 523 .
- Stabbing member 523 extends axially from coupling member 522 and comprises a rigid tubular pipe 527 having an angle mule shoe tip 528 at upper end 520 a. Tip 528 facilities the axially insertion of stabbing member 523 into funnel guide 516 of pipe 513 and passage 511 at lower end 510 b.
- hydrocarbon collection system 500 is shown being deployed subsea and positioned to capture hydrocarbons discharged from exhaust conduit 335 . More specifically, in FIG. 21 , overshot tool 520 is shown being lowered subsea; in FIG. 22 , overshot tool 520 is shown being positioned over outlet end 335 b of conduit 335 ; in FIG. 23 , overshot tool 520 is shown being mounted to exhaust conduit 335 ; in FIG. 24 , connection member 510 is shown being lowered subsea; in FIG. 25 , connection member 510 is shown being moved laterally end 520 a of overshot tool 520 ; and in FIG. 26 , connection member 510 is shown being lowered and mounted to overshot tool 520 .
- one or more ROVs 170 are preferably employed to aid in positioning of overshot tool 520 and connection member 510 , as well as to monitor overshot tool 520 , connection member 510 , pressure control device 300 , BOP 120 , and capping stack 200 .
- overshot tool 520 is shown being controllably lowered subsea with a wireline cable 180 releasably coupled to tool 520 and extending to a surface vessel.
- a winch or crane mounted to a surface vessel is preferably employed to support and lower tool 520 on cables 180 .
- overshot tool 520 is lowered subsea front a location generally above and laterally offset from exhaust conduit 335 to maintain overshot tool 520 outside of plume 160 , thereby reducing the potential for the formation of hydrates therein.
- Overshot tool 520 is lowered laterally offset front exhaust conduit 335 and outside of plume 160 until lower end 520 b is slightly above outlet end 335 b.
- ROVs 170 monitor the position of tool 520 relative to capping slack 200 and device 300 .
- tool 520 is moved laterally into position immediately above end 335 b with tool 520 substantially coaxially aligned with end 335 b.
- One or more ROVs 170 may utilize their claws 172 and handles 427 to guide tool 520 into proper alignment relative to exhaust conduit 335 .
- connection member 510 is coupled to the lower end of a tubular string 700 at the surface 102 with J-latch coupling 412 , and is then controllably lowered subsea with string 700 .
- a derrick or other suitable device mounted to a surface vessel is preferably employed to support and lower device 300 on string 700 .
- connection member 510 is lowered subsea from a location generally above and laterally offset from overshot tool 520 to maintain connection member 510 outside of plume 160 , thereby reducing the potential for the formation of hydrates therein.
- Connection member 510 is lowered laterally offset from overshot tool 520 and outside of plume 160 until lower end 510 b is slightly above tip 528 at upper end 520 a.
- ROVs 170 monitor the position of connection member 510 relative to tool 520 , capping stack 200 , and device 300 .
- connection member 510 is moved laterally into position immediately above end 520 a and substantially coaxially aligned with stabbing member 523 .
- One or more ROVs 170 may utilize their claws 172 and handles 517 to guide connection member 510 into proper alignment relative to stabbing member 523 .
- connection member 510 With connection member 510 positioned immediately above and generally coaxially aligned with stabbing member 523 , string 700 lowers connection member 510 axially downward, thereby inserting and axially advancing end 520 a of overshot tool 520 into passage 511 of connection member 510 .
- Funnel guide 516 at end 510 b and mule shoe tip 528 at upper end 520 a facilitate the insertion and axial advancement of stabbing member 523 into pipe 513 in the event connection member 510 is slightly out of alignment with stabbing member 523 .
- Stabbing member 523 is axially advanced through pipe 513 until tip 528 is axially proximal and below flex joint 518 , thereby allowing J-latch coupling 412 to pivot about flex joint 518 relative to pipe 513 and stabbing member 523 disposed therein.
- connection member 510 During collection operations, the weight of connection member 510 is supported by string 700 to minimize the transfer of any loads to overshot tool 520 , exhaust conduit 335 , and pressure control device 300 . Minimizing loads on exhaust conduit 335 as well as the flexibility of connection member 510 due to flex joint 518 offers the potential to reduce the chances of inadvertently damaging conduit 335 and/or control device 300 , particularly if the deployment vessel at the surface 102 experiences a sudden lateral or vertical movement.
- System 600 for capturing hydrocarbon fluids exhausted from a subsea discharge site (e.g., hydrocarbons discharged from exhaust conduit 335 ) is shown.
- System 600 has a central or longitudinal axis 605 , a first or upper end 600 a, and a second or lower end 600 b opposite end 600 a .
- system 600 includes a connection member 610 extending axially from upper end 600 a, a top hat 620 coupled to connection member 610 , and an annular flexible skirt 630 extending from top hat 620 to lower end 600 b.
- Connection member 610 has a central axis 615 coincident with axis 605 , a first or upper end 610 a defining upper end 600 a of system 600 , a second or lower end 610 b coupled to top hat 620 , and a central through bore 611 extending axially between ends 610 a, b .
- connection member 610 includes a J-latch coupling 412 as previously described extending axially from upper end 610 a.
- top hat 620 has a central axis 625 coaxially aligned with axis 615 , a first or upper end 620 a coupled to lower end 610 b, and a second or lower end 620 b .
- Top hat 620 is an annular inverted funnel defining an inner flow passage extending between ends 620 a, b .
- the flow passage has an inlet at lower end 620 b and an outlet at upper end 620 a in fluid communication with bore 611 of connection member 610 .
- top hat 620 also includes a plurality of circumferentially spaced auxiliary outlets 621 proximal upper end 620 a and an ROV control panel 622 .
- Each outlet 621 includes an ROV operated valve 623 that controls the flow of fluids through the corresponding outlet 621 .
- Control panel 622 includes a plurality of receptacles for injecting a hydrate inhibitor (e.g., methanol) into top hat 620 to reduce and/or prevent the formation of hydrates within top hat 620 and downstream of top hat 620 .
- a pair of handles 624 that extend radially from top hat 620 and enable ROVs to manipulate, rotate, and position top hat 620 during subsea deployment. Additional details and examples of top hats that may be used as top hat 620 are disclosed in U.S. Patent Application Ser. No. 61/384,358 filed Sep. 20, 2010 and entitled “Containment Cap for Controlling a Subsea Blowout,” which is hereby incorporated herein by reference in its entirety.
- Annular skirt 630 hangs from lower end 620 b of top hat 620 .
- skirt 630 comprises a plurality of flexible generally rectangular panels 631 positioned circumferentially adjacent each other. More specifically, in this embodiment, each panel 631 is a rubber sheet having an axial length of four feet.
- hydrocarbon collection system 600 is shown being deployed subsea and positioned to capture hydrocarbons discharged from exhaust conduit 335 . More specifically, in FIG. 28 , system 600 is shown being lowered subsea; in FIG. 29 , system 600 is shown being moved laterally over conduit 335 ; and in FIG. 30 , system 600 is shown positioned about end 335 b of exhaust conduit 335 .
- one or more ROVs 170 are preferably employed to aid in positioning collection system 600 and monitoring collection system 600 , pressure control device 300 , BOP 120 , and capping stack 200 .
- system 600 is coupled to the lower end of a tubular string 700 at the surface 102 with J-latch coupling 412 , and is then controllably lowered subsea with string 700 .
- a derrick or other suitable device mounted to a surface vessel is preferably employed to support and lower system 600 on string 700 .
- system 600 is lowered subsea from a location generally above and laterally offset from exhaust conduit 335 to maintain system 600 outside of plume 160 , thereby reducing the potential for the formation of hydrates therein.
- a hydrate inhibitor e.g., methanol
- ROV 170 and control panel 622 Any injected inhibitor is free to flow upward within the remainder of system 600 and string 700 .
- system 600 is lowered laterally offset from exhaust conduit 335 and outside of plume 160 until outlet end 335 b is axially positioned between ends 600 b, 620 b.
- ROVs 170 monitor the position of system 600 relative to capping stack 200 and device 300 .
- system 600 is moved laterally to position end 335 b inside skirt 630 .
- circumferentially adjacent flexible panels 631 are urged apart to allow end 335 b to pass therebetween and into skirt 630 .
- One or more ROVs 170 may utilize their claws 172 and handles 624 to guide system 600 as it is moved laterally across end 335 b.
- hydrocarbon fluids discharged from exhaust conduit 335 flow upward through skirt 630 , top hat 620 , connection member 610 , and string 700 to the surface where they may be captured and contained.
- a hydrate inhibitor e.g., methanol
- the weight of system 600 is supported by string 700 to minimize the transfer of any loads to exhaust conduit 335 and pressure control device 300 .
- Minimizing loads on exhaust conduit 335 as well as the flexibility of conduit 430 of collection system 400 offers the potential to reduce the chances of inadvertently damaging conduit 335 and/or control device 300 , particularly if the deployment vessel at the surface 102 experiences a sudden lateral or vertical movement.
- embodiments of systems and methods described herein may be employed to contain and collect at least a portion of the hydrocarbon fluids exhausted from a subsea discharge site.
- system 400 , system 500 , and system 600 have been described as containing and collecting hydrocarbon fluids emitted from pressure control device 300 coupled to side outlet 214 of capping stack 200
- embodiments described herein may be used to contain and collect hydrocarbons vented from any subsea discharge site including, without limitation, a subsea BOP or capping stack side outlet, a subsea manifold outlet, a subsea production tree outlet or leak, an outlet with an isolation valve operated locally by an ROV or operated remotely by a subsea control system, a normally closed outlet fitted with a pressure safety valve (e.g. relief valve), or a burst disc designed to open automatically if a pre-determined pressure differential is exceeded
- a pressure safety valve e.g. relief valve
Abstract
A method for capturing at least a portion of hydrocarbon fluids vented into the surrounding sea from a subsea discharge site comprises (a) mounting a pressure control device to the subsea discharge site. Further, the method comprises (b) flowing the vented hydrocarbon fluids from the subsea discharge site through the pressure control device. Still further, the method comprises (c) positioning a collection system subsea on a lower end of a tubular string. Moreover, the method comprises (d) flowing the vented hydrocarbons fluids from the pressure control device into the collection system and through the tubular siring after (b). The method also comprises (e) minimizing lateral and vertical loads applied to the subsea discharge site by the collection system.
Description
- This application claims benefit of U.S. provisional patent application Ser. No. 61/558,827 filed Nov. 11, 2011, and entitled “Systems and Methods for Collecting Hydrocarbons Vented from a Subsea Discharge Site,” which is hereby incorporated herein by reference in its entirety.
- Not applicable.
- 1. Field of the Invention
- The invention relates generally to systems and methods for collecting hydrocarbons vented from a subsea discharge site. More particularly, the invention relates to systems and methods for collecting the bulk hydrocarbon flow from a pre-determined, controlled subsea pressure exhaust vent point.
- 2. Background of the Technology
- In offshore drilling operations, a blowout preventer (BOP) is installed on a wellhead at the sea floor and a lower marine riser package (LMRP) is 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. A choke line and a kill line are also suspended from the rig and coupled to the BOP, usually as part of the drilling riser assembly.
- 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 high-pressure gas and/or liquids from the well. Thus, the BOP and LMRP are used as safety devices that close, isolate, and seal the wellbore. Heavier drilling mud may be delivered through the drill string, forcing fluid from the annulus through the choke line or kill line to protect the well equipment disposed above the BOP and LMRP from the high pressures associated with the formation fluid. Assuming the structural integrity of the well has not been compromised, drilling operations may resume. However, if drilling operations cannot be resumed, cement or heavier drilling mud is delivered into the well bore to kill the well.
- In some scenarios, it may be necessary to vent hydrocarbon fluids into the surrounding sea to manage wellbore pressures and/or protect equipment from damage. This situation would typically arise where a fluid conduit (e.g., choke line) for flowing the exhausted hydrocarbon fluids from the subsea vent point to the surface is not already in place or has been damaged. For example, a subsea blowout may damage the subsea BOP, LMRP, or riser, potentially resulting in the discharge of hydrocarbons into the surrounding sea. One approach to capping and shutting-in the subsea well is to lower a capping stack subsea, couple the capping stack to the upper end of the subsea BOP or LMRP that is discharging hydrocarbons, and then utilize the capping stack to shut-in the well. Examples of capping stacks, methods of deploying and installing capping stacks, and methods of containing a subsea well with capping stacks are described in U.S. Patent Application Ser. No. 61/475,032 filed Apr. 13, 2011 and entitled “Systems and Methods for Capping a Subsea Well,” which is hereby incorporated herein by reference in its entirety for all purposes. However, due to pressure limitations of the wellbore, ay not be desirable or safe to completely shut-in the well with the capping stack. Accordingly, hydrocarbon fluids may be controllably vented from the well through the capping stack into the surrounding sea.
- As another example, a sudden and potentially prolonged release of hydrocarbon fluids at a subsea discharge site may result from the shut-in of a surface flow containment vessel during a cap and flow response operation. In particular, a normally closed discharge site protected by a pressure safety valve or burst disc assembly may open in response to a shut-in and associated wellbore pressure increase. As still yet another example, a choke outlet on a capping stack mounted to a subsea BOP may be allowed to vent hydrocarbons subsea during a relief well bottom-kill operation.
- Traditionally, hydrocarbon fluids discharged into the sea are allowed to rise to the surface, where they are treated with chemical dispersing agents, which 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. Typically, dispersants are sprayed onto the oil at the surface of the water. 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). 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.
- Accordingly, there remains a need in the art for systems and methods to contain and capture hydrocarbon fluids discharged subsea. Such systems and methods would be particularly well-received if they offered the potential to capture the hydrocarbon fluids at the subsea discharge site to reduce and/or eliminate the need to apply chemical dispersants at the surface.
- These and other needs in the art are addressed in one embodiment by a method for capturing at least a portion of hydrocarbon fluids vented into the surrounding sea from a subsea discharge site. In an embodiment, the method comprises (a) mounting a pressure control device to the subsea discharge site. Further, the method comprises (b) flowing the vented hydrocarbon fluids from the subsea discharge site through the pressure control device. Still further, the method comprises (c) positioning a collection system subsea on a lower end of a tubular string. Moreover, the method comprises (d) flowing the vented hydrocarbons fluids from the pressure control device into the collection system and through the tubular string after (b). The method also comprises (e) minimizing lateral loads applied to the subsea discharge site by the collection system.
- These and other needs in the art are addressed in another embodiment by an assembly for capturing at least a portion of hydrocarbon fluids vented into the surrounding sea from a subsea discharge site. In an embodiment, the assembly comprises a collection system including a connection member, an overshot tool, and a flexible conduit extending from the overshot tool to the connection member. The connection member has a central axis, an upper end, a lower end, and a flow passage extending axially from the upper end to the lower end, the upper end configured to releasably connect to a lower end of a tubular string and the lower end coupled to the flexible conduit. The overshot tool has a central axis, an upper end coupled to the flexible conduit, a lower end, and a flow passage extending from the lower end of the overshot tool to the upper end of the overshot tool. The overshot tool includes an elongate slot extending axially from the lower end and extending radially through the overshot tool to the flow passage of the overshot tool. The flexible conduit is in fluid communication with the flow passage of the overshot tool and the flow passage of the connection member.
- These and other needs in the art are addressed in another embodiment by an assembly for capturing at least a portion of hydrocarbon fluids vented into the surrounding sea from a subsea discharge site. In an embodiment, the assembly comprises a collection system including a connection member and an overshot tool. The connection member has a central axis, an upper end, a lower end, and a flow passage extending axially from the upper end to the lower end, the upper end configured to releasably connect to a lower end of a tubular string and the lower end comprising a funnel guide. The overshot tool has a central axis, an upper end, a lower end, a flow passage extending from the lower end of the overshot tool to the upper end of the overshot tool. The overshot tool includes a coupling member at the lower end of the overshot tool and an elongate stabbing member extending axially from the coupling member to the upper end of the overshot tool. The stabbing member is slidingly disposed in the flow passage of the connection member.
- Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods. The foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood. 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. It should be appreciated by those skilled in the art that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
- For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings in which:
-
FIG. 1 is a schematic view of an embodiment of an offshore drilling system; -
FIG. 2 is a schematic view of the offshore drilling system ofFIG. 1 damaged by a subsea blowout; -
FIG. 3 is a schematic front view of an embodiment of a capping stack mounted to the BOP ofFIG. 2 ; -
FIG. 4 is an enlarged schematic front view of the capping stack ofFIG. 3 ; -
FIG. 5 is an enlarged schematic side view of the capping stack ofFIG. 3 ; -
FIG. 6 is a partial cut-away side view of an embodiment of a subsea pressure control device for connecting to one of the side outlets of the capping stack ofFIG. 3 ; -
FIG. 7 is a front view of the pressure control device ofFIG. 6 ; -
FIGS. 8-11 are sequential schematic views of the deployment and installation of the pressure control device ofFIG. 6 onto the capping stack ofFIG. 3 ; -
FIG. 12 is a side view of an embodiment of a collection apparatus for capturing hydrocarbon fluids exhausted from a subsea discharge site; -
FIG. 13 is an enlarged view of the connection member ofFIG. 12 ; -
FIG. 14 is an enlarged view of the overshot tool ofFIG. 12 ; -
FIGS. 15-17 are sequential schematic views illustrating the collection apparatus ofFIG. 12 being deployed subsea and positioned to collect hydrocarbons discharged from the pressure control device ofFIG. 11 ; -
FIG. 18 is a side view of an embodiment of a collection assembly for capturing hydrocarbon fluids exhausted from a subsea discharge site; -
FIG. 19 is an enlarged view of the connection member ofFIG. 18 ; -
FIG. 20 is an enlarged view of the overshot tool ofFIG. 18 ; -
FIGS. 21-26 are sequential views illustrating the collection assembly ofFIG. 17 being deployed subsea and positioned to collect hydrocarbons discharged from the pressure control device ofFIG. 11 ; -
FIG. 27 is a front view of an embodiment of a collection apparatus for capturing hydrocarbon fluids exhausted from a subsea discharge site; and -
FIGS. 28-30 are sequential views illustrating the collection apparatus ofFIG. 27 being deployed subsea and positioned to collect hydrocarbons discharged from the pressure control device ofFIG. 11 . - 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 intimate 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
FIG. 1 , an embodiment of anoffshore system 100 for drilling and/or producing awellbore 101 is shown. In this embodiment,system 100 includes an offshore platform or mobile offshore drilling unit (MODU) 110 at thesea surface 102, a subsea blowout preventer (BOP) 120 mounted to awellhead 130 at thesea floor 103, and a lower marine riser package (LMRP) 140 attached toBOP 120.Platform 110 is equipped with aderrick 111 that supports a hoist (not shown). Adrilling riser 115 extends fromplatform 110 toLMRP 140. In general,riser 115 is a large-diameter pipe that connectsLMRP 140 to theMODU 110. During drilling operations,riser 115 takes mud returns to theMODU 110. Casing 131 extends fromwellhead 130 intosubterranean wellbore 101. - Downhole operations are carried out by a tubular string 116 (e.g., drillstring, production tubing string, coiled tubing, etc.) that is supported by
derrick 111 and extends fromMODU 110 throughriser 115,LMRP 140,BOP 120, and into casedwellbore 101. Adownhole tool 117 is connected to the lower end oftubular string 116. In general,downhole tool 117 may comprise any suitable downhole tool(s) for drilling, completing, evaluating and/or producingwellbore 101 including, without limitation, drill bits, packers, testing equipment, perforating guns, and like. During downhole operations,string 116, and hencetool 117 coupled thereto, may move axially, radially, and/or rotationally relative toriser 115,LMRP 140,BOP 120, andcasing 131. -
BOP 120 andLMRP 140 are configured to controllably sealwellbore 101 and contain hydrocarbon fluids therein. Specifically,BOP 120 has a central orlongitudinal axis 125 and includes abody 123 with an upper end releasably secured toLMRP 140, a lower end releasably secured towellhead 130, and amain bore 124 extending axially between the upper and lower ends. Main bore 124 is coaxially aligned withwellbore 101, thereby allowing fluid communication betweenwellbore 101 andmain bore 124. In this embodiment,BOP 120 is releasably coupled toLMRP 140 andwellhead 130 with hydraulically actuated, mechanical wellhead-type connectors 150. In general,connectors 150 may comprise any suitable releasable wellhead-type mechanical connector such as the H-4® profile subsea connector available from VetcoGray Inc. of Houston, Tex. or the DWHC profile subsea connector available from Cameron International Corporation of Houston, Tex. Typically, such wellhead-type mechanical connectors (e.g., connectors 150) comprise a male component or coupling that is inserted into and releasably locked within a mating female component or coupling. In addition,BOP 120 includes a plurality of axially stacked sets of opposed rams—opposed blind shear rams orblades 127 for severingtubular string 116 and sealing offwellbore 101 fromriser 115, opposedblind rams 128 for sealing offwellbore 101 when no string (e.g., string 116) or tubular extends throughmain bore 124, and opposed pipe rams 129 for engagingstring 116 and sealing the annulus aroundtubular string 116. Each set oframs string 116 and/ormain bore 124 whenrams -
Opposed rams main bore 124 and support rams 127, 128, 129 as they move into and out ofmain bore 124. Each set oframs main bore 124 and do not interfere withtubular string 116 or other hardware that may extend throughmain bore 124. However, in the closed positions, rams 127, 128, 129 are radially advanced intomain bore 124 to close off and seal main bore 124 (e.g., rams 127, 128) or the annulus around tubular string 116 (e.g., rams 129). Each set oframs actuators 126. In particular, each actuator 126 hydraulically moves a piston within a cylinder to move a drive rod coupled to oneram - Referring still to
FIG. 1 ,LMRP 140 has abody 141 with an upper end connected to the lower end ofriser 115, a lower end releasably secured toBOP 120 withconnector 150, and athroughbore 142 extending axially between the upper and lower ends.Throughbore 142 is coaxially aligned withmain bore 124 ofBOP 120, thereby allowing fluid communication betweenthroughbore 142 andmain bore 124.LMRP 140 also includes anannular blowout preventer 142 a comprising an annular elastomeric sealing element that is mechanically squeezed radially inward to seal on a tubular extending through bore 142 (e.g.,string 116, casing, drillpipe, drill collar, etc.) or seal offbore 142. Thus,annular BOP 142 a has the ability to seal on a variety of pipe sizes and seal offbore 142 when no tubular is extending therethrough. - In this embodiment, the upper end of
LMRP 140 comprises a riser flex joint 143 that allowsriser 115 to deflect angularly relative toBOP 120 andLMRP 140 while hydrocarbon fluids flow fromwellbore 101,BOP 120 andLMRP 140 intoriser 115. Flex joint 143 includes a riser adapter 145 with anannular flange 145 a at its upper end for coupling to a matingannular flange 118 at the lower end ofriser 115 or to alternative devices. AlthoughLMRP 140 has been shown and described as including a particular flex joint 143, in general, any suitable riser flex joint may be employed inLMRP 140. - As previously described, in this embodiment,
BOP 120 includes three sets of rams (one set of shear rams 127, one set of pipe rams 129, and one blind rams 128), however, in other embodiments, the BOP (e.g., BOP 120) may include a different number of rams (e.g., four sets of rams), different types of rams (e.g., two sets of shear rams and one set of pipe rams), an annular BOP (e.g.,annular BOP 142 a), or combinations thereof. Likewise, althoughLMRP 140 is shown and described as including oneannular BOP 142 a, in other embodiments, the LMRP (e.g., LMRP 140) may include a different number of annular BOPs (e.g., two sets of annular BOPs), different types of rams (e.g., shear rams), or combinations thereof. - Referring now to
FIG. 2 , during a “kick” or surge of formation fluid pressure inwellbore 101, resulting in a blowout, potentially resulting in the discharge of such hydrocarbon fluids subsea in the form of aplume 160 that extends to thesea surface 102. InFIG. 2 ,system 100 is shown after a subsea blowout. To contain and control the subsea well and the emission of hydrocarbon fluids, a capping stack may be deployed subsea and installed ontoBOP 120 as described in U.S. Patent Application Ser. No. 61/475,032 filed Apr. 13, 2011 and entitled “Systems and Methods for Capping a Subsea Well,” which is hereby incorporated herein by reference in its entirety for all purposes. - Referring now to
FIGS. 3-5 , anexemplary capping stack 200 for capping and controllingwellbore 101 previously described (FIG. 2 ) is shown. In this embodiment, cappingstack 200 comprises a drilling BOP 210 similar toBOP 120 previously described. In particular, BOP 210 has a central orlongitudinal axis 215, and includes abody 212 with a first orupper end 212 a, a second orlower end 212 b, and amain bore 213 extending axially between ends 212 a, b.Upper end 212 a comprises a male coupling of a wellhead-type connector 150 andlower end 212 b comprises the female coupling of a wellhead-type connector 150. In addition, BOP 210 includes a plurality of axially stacked sets of opposed rams—one set of opposed blind shear rams orblades 127, one set of opposedblind rams 128, and one set of opposed pipe rams 129, each as previously described.Opposed rams main bore 213 and support rams 127, 128, 129 as they move into and out ofmain bore 213. Each set oframs main bore 213, and in the closed positions, rams 127, 128, 129 are radially advanced intomain bore 213 to close off and sealmain bore 213. Each set oframs actuators 126 as previously described. As best shown inFIG. 4 , a plurality of T-handles 219 extend radially outward frombody 212, and enable ROVs to manipulate, rotate, andposition stack 200 during subsea deployment. - Referring still to
FIGS. 3-5 , in this embodiment, stack 200 also includes a plurality ofside outlets 214 extending frommain bore 213 throughbody 212. Eachside outlet 214 has afirst end 214 a in fluid communication withmain bore 213, asecond end 214 b distalmain bore 213 and extending frombody 212, and an isolation valve 214 c that controls the flow of fluids through theside outlet 214.Side outlets 214 provide a means for relieving the pressure of fluids inmain bore 213. For example, during and after a well shut in, there may be a risk of the fluid pressure in the wellbore (e.g., wellbore 101) exceeding the pressure limits of the containment hardware coupled to the wellhead (e.g.,BOP 120, BOP 210) and/or the casing (e.g., 131). Exceeding the pressure containment limits of the containment hardware or the casing may result in a blowout. Accordingly, as shown inFIG. 3 ,main bore 213, one ormore side outlets 214, or combinations thereof may be opened to vent wellbore fluids and relieve pressure withinwellbore 101.Second end 214 b of eachside outlet 214 comprises an upward facing male component orcoupling 216 that is received by and releasably locked within a mating female component or coupling. - Referring now to
FIGS. 6 and 7 , an embodiment of a wellborepressure control device 300 that can be releasably coupled to aside outlet 214 of cappingstack 200 to control the discharge of hydrocarbon fluids and manage wellbore fluid pressures is shown. In this embodiment,pressure control device 300 is a choke assembly having acentral axis 305, a first orupper end 300 a, and a second orlower end 300 b oppositeend 300 a. In addition,choke assembly 300 includes anannular receiving guide 310 atlower end 300 b, a downward facing female component orcoupling 320 axiallyadjacent guide 310, achoke valve 330 atupper end 300 a, and a tubularfluid conduit 340 extending axially betweencoupling 320 and chokevalve 330. - Receiving
guide 310 includes aninner passage 311 extending axially fromlower end 300 b tocoupling 320. Atlower end 300 b,passage 311 comprises an invertedfrustoconical guide surface 312 configured to receive and guidesecond end 214 b ofside outlet 214 intocoupling 320. A pair ofhandles 313 extend radially outward fromguide 310 and enable ROVs to manipulate, rotate, andposition device 300 during subsea deployment. -
Female coupling 320 is configured to matingly receive and releasably lock ontocoupling 216 ofside outlet 214, thereby securingchoke assembly 300 toside outlet 214. In this embodiment,coupling 320 is a hydraulically actuated, mechanical connector that releasably locks onto and sealingly engagescoupling 216. More specifically, when coupling 216 atend 214 b ofside outlet 214 is sufficiently seated withinconnector 320,connector 320 is hydraulically actuated to releasably lock ontoend 214 b. In general,couplings side outlet 214 and chokeassembly 300. Examples of suitable types of couplings include, without limitation, three inch Choke and Kill Connector available from Cameron international Corporation of Houston, Tex.; the Optima Subsea Connector available from Vector Group, Inc. of Houston, Tex.; and the RIC and RAC connectors available from Oil States international, Inc. of Arlington, Tex. - Referring still to
FIGS. 6 and 7 , chokevalve 330 has aninlet 331, anoutlet 332, and is configured to choke the flow of fluids throughpressure control device 300. Atubular exhaust conduit 335 attached to chokevalve 330 has alower inlet end 335 a in fluid communication withoutlet 332 and an open, upper outlet end 336 b oppositeend 335 a.Conduit 340 extends from coupling 320 to chokevalve 330 and provides fluid communication betweencoupling 320 andinlet 331. Thus, whendevice 300 is mounted toside outlet 214, hydrocarbon fluids flowing throughside outlet 214exit end 214 b withincoupling 320 and flow throughconduit 340 andinlet 331 intochoke valve 330, where the hydrocarbon fluid flow is restricted. The choked or restricted fluid flow exits chokevalve 330 throughoutlet 332, and flows throughconduit 335 into the surrounding environment atopen end 335 b. In this embodiment,conduit 335 includes a 90° bend between ends 335 a, b that allows inlet end 335 a to be oriented perpendicular toaxis 305 and outlet end 335 b to be oriented parallel toaxis 305. - In this embodiment,
pressure control device 300 also includes anROV control panel 350 that enables a subsea ROV to operatechoke valve 330, as well as operate the other functions ofdevice 300. In particular,device 300 includes a hydraulicfluid control valve 351 a, a testfluid control valve 352 a, a chemicalinjection control valve 353 a, and a chemicaldispersant control valve 354 a. Eachvalve panel 350 and is accessed and controlled subsea with an ROV via an associatedvalve actuation member control panel 350. Eachvalve FIGS. 6 and 7 . In particular, the inlet ofvalve 351 a is connected to a pressurized hydraulic fluid supply line, inlet ofvalve 352 a is connected to a test fluid supply line, the inlet ofvalve 353 a is connected to a chemical injection supply line, and an inlet ofvalve 354 a is connected to a chemical dispersant supply line. The outlet ofvalve 351 a selectively supplies pressurized hydraulic fluid toconnector 320 to actuateconnector 320 between the locked and unlocked positions; the outlet ofvalve 352 a selectively supplies testing fluids (e.g., glycol, methanol, etc.) todevice 300 proximalchoke valve inlet 331; the outlet ofvalve 353 a selectively supplies chemicals (e.g., methanol) to inlet end 335 a ofexhaust conduit 335; and the outlet ofvalve 354 a selectively supplies dispersant (e.g., Corexit® EC9500A available from Nalco Company of Naperville, Ill.) toconduit 335 betweenends 335 a, b. A chokevalve actuator member 355 is positioned axially abovecontrol panel 350 and allows a subsea ROV to actuatechoke valve 330. - Referring now to
FIGS. 8-11 ,pressure control device 300 is shown being deployed and installed subsea onend 214 b of oneside outlet 214 to choke and control the flow of hydrocarbons exhausted from cappingstack 200. More specifically, inFIG. 8 ,device 300 is shown being lowered subsea; inFIG. 9 ,device 300 is shown being moved laterally overend 214 b of oneside outlet 214; inFIG. 10 ,device 300 is shown being generally coaxially aligned withend 214 b and lowered into engagement withside outlet 214; and inFIG. 11 ,device 300 is shown being secured to end 214 b ofside outlet 214. For purposes of clarity and further explanation, theside outlet 214 to whichdevice 300 is mounted (theside outlet 214 shown on the right inFIGS. 8-11 ) is designated withreference numeral 214′ to distinguish it from the other side outlet 214 (theside outlet 214 shown on the left inFIGS. 8-11 ), which is designated withreference numeral 214″. - To simplify installation operations and enable
device 300 to be installed easier, valve 214 c associated with theside outlet 214′ is preferably closed prior to and during installation ofdevice 300. However, to ensure relief of pressure withinmain bore 213 and wellbore 101, valve 214 c associated with theother side outlet 214″ is preferably open prior to and during installation ofdevice 300. In the exemplary installation sequence shown inFIGS. 8-11 , valve 214 c of theside outlet 214′ is closed prior to and during installation ofdevice 300, valve 214 c ofside outlet 214″ is open prior to and during installation ofdevice 300, andmain bore 213 is closed downstream ofends 214 a (e.g., one ormore rams device 300. Following installation ofdevice 300, valve 214 c ofside outlet 214′ is opened, valve 214 c ofside outlet 214″ is closed,main bore 213 remains closed, anddevice 300 is employed. to choke the flow throughside outlet 214′. - For subsea deployment and installation of
device 300, one or more remote operated vehicles (ROVs) are preferably employed to aid inpositioning device 300,monitoring device 300,BOP 120, and cappingstack 200, and selectively actuatingvalves ROVs 170 are provided to facilitate the installation and operation ofdevice 300 as well asmonitor device 300 andBOPs 120, 210. EachROV 170 includes anarm 171 having aclaw 172, asubsea camera 173 for viewing the subsea operations (e.g., the relative positions ofstack 200 anddevice 300,plume 160, the positions and movement ofarms 170 andclaws 172, etc.), and an umbilical 174. Streaming video and/or images fromcameras 173 are communicated to the surface or other remote location via umbilical 174 for viewing on a live or periodic basis.Arms 171 andclaws 172 are controlled via commands sent from the surface or other remote location toROV 170 through umbilical 174. - Referring first to
FIG. 8 , in this embodiment,device 300 is shown being controllably lowered subsea with a plurality ofwireline cables 180 secured todevice 300 and extending to a surface vessel. A winch or crane mounted to a surface vessel is preferably employed to support andlower device 300 oncables 180. - Using
cables 180,device 300 is lowered subsea under its own weight from a location generally above and laterally offset fromwellbore 101 and cappingstack 200. More specifically, during deployment,device 300 is preferably maintained outside ofplume 160 of hydrocarbon fluids emitted fromcap 200. Loweringdevice 300 subsea inplume 160 may trigger the undesirable formation of hydrates withindevice 300, particularly at elevations substantially abovesea floor 103 where the temperature of hydrocarbons inplume 160 is relatively low. - Moving now to
FIG. 9 ,device 300 is lowered laterally offset fromstack 200 and outside ofplume 160 untilguide 310 is slightly aboveend 214 b ofclosed side outlet 214′. Asdevice 300 descends and approaches cappingstack 200,ROVs 170 monitor the position ofdevice 300 relative to cappingstack 200. Next, as shown inFIG. 10 ,device 300 is moved laterally into position immediately aboveend 214 b ofside outlet 214′ withguide 310 substantially coaxially aligned withend 214 b. One ormore ROVs 170 may utilize theirclaws 172 and handles 313 to guide and rotatedevice 300 into proper alignment relative to end 214 b. - With
guide 310 positioned immediately above and generally coaxially aligned withend 214 b ofside outlet 214′,cables 180lower device 300 axially downward, thereby inserting and axially advancingend 214 b ofside outlet 214′ intoguide 310 andcoupling 320 untilend 214 b is sufficiently seated incoupling 320. Thefrustoconical guide surface 312 atlower end 300 b functions to guideend 214 b intocoupling 320, even ifend 214 b is initially slightly misaligned withguide 310. Prior to movingdevice 300 laterally overside outlet 214′,choke valve 330 is preferably transitioned to the open position.Choke valve 330 may be transitioned to the open position at thesurface 102 prior to deployment, or subsea via one ormore ROVs 170. Sinceoutlet 214′ was previously closed, there is little to no resistance to the axial insertion ofend 214 b intoguide 310 andcoupling 320. - With
end 214 b sufficiently seated incoupling 320, anROV 170 actuatescoupling 320 to lock ontomating coupling 216 atend 214 b, thereby securingdevice 300 ontoside outlet 214′. Oncedevice 300 is securely coupled toside outlet 214′,cables 180 may be decoupled fromstack 200 withROVs 170 and removed to the surface. With a sealed, secure connection betweendevice 300 andside outlet 214′, valve 214 c ofside outlet 214′ is opened, thereby allowing emitted hydrocarbon fluid to flow freely throughoutlets 214′, 214″ anddevice 300. Next, valve 214 c ofoutlet 214″ is closed, and chokevalve 330 may be adjusted (e.g., transitioned to a partially closed position) with anROV 170 to achieve the desired pressure and flow throughside outlet 214′. In some cases, it may be necessary to continue to vent hydrocarbon fluids throughside outlet 214′ anddevice 300 to manage wellbore pressures. Any such vented hydrocarbon fluids fromdevice 300 or other subsea structure (e.g., subsea manifold) are preferably captured and contained to minimize environmental impacts. Embodiments of system and methods for capturing and collecting hydrocarbons vented fromdevice 300 following connection ofdevice 300 toside outlet 214′ are described in more detail below. - Referring now to
FIGS. 4 , an embodiment ofcollection system 400 for capturing hydrocarbon fluids exhausted from a subsea discharge site (e.g., hydrocarbons discharged from exhaust conduit 335) is shown.System 400 has a central orlongitudinal axis 405, a first orupper end 400 a, and a second orlower end 400 b oppositeend 400 a. In this embodiment,system 400 includes aconnection member 410 atupper end 400 a, anovershot tool 420 atlower end 400 b, and aflexible conduit 430 extending fromconnection member 410 toovershot tool 420.Connection member 410,tool 420, andflexible conduit 430 are connected end-to-end withconnectors 440. - As best shown in
FIG. 13 ,connection member 410 has a central axis 415 coincident withaxis 405, a first orupper end 410 a definingupper end 400 a ofsystem 400, a second orlower end 410 b coupled toconduit 430 withconnector 440, and a central throughbore 411 extending axially between ends 410 a, b. In this embodiment,connection member 410 includes a J-latch coupling 412 extending axially fromupper end 410 a, anelongate pipe 413 extending axially fromlower end 410 b to J-latch coupling 412, and an ROV control panel 414 attached topipe 413. ROV control panel 414 is disposed alongpipe 413 axially belowlatch coupling 412 and includes a stabbing port for injecting a hydrate inhibitor (e.g., methanol) intopipe 413 to reduce and/or prevent the formation of hydrates downstream ofpipe 413. - J-
latch coupling 412 comprises a rigidtubular body 416 having anannular funnel guide 417 atupper end 410 a and a pair of circumferentially spaced J-slots 418 positioned axiallyadjacent guide 417. In this embodiment, J-slots 418 are angularly spaced 180° apart relative to axis 415. As is known in the art, a J-slot defines a track on a first device that releasably receives a mating pin on a second device to releasably couple the first and second devices. Once made-up, a J-slot connection is capable of transferring tensile and compression axial loads, as well as rotational torque. In this embodiment, each J-slot 418 extends radially throughbody 416 to bore 411 and is configured to slidingly receive a pin on the lower end of a tubular string (e.g., drillstring) to releasablycouple connection member 410 andsystem 400 to the tubular string for subsea deployment and manipulation. - Referring now to
FIG. 14 , overshottool 420 has a central axis 425 coincident withaxis 405, a first orupper end 420 a coupled toconduit 430 with oneconnector 440, a second orlower end 420b defining end 400 b ofsystem 400, and a central throughbore 421 extending axially between ends 420 a, b. In this embodiment, overshottool 420 comprises a rigidtubular body 422 having anelongate slot 423 extending axially fromlower end 420 b and extending radially throughbody 422 to bore 421.Slot 423 defines opposed lateral edges 424. In this embodiment, aresilient rubber bumper 426 is mounted to eachedge 424 proximal the upper end ofslot 423. As will be described in more detail below,bumpers 426 provide a resilient, flexible surface configured to slidingly engageconduit 335 ofpressure control device 300 whensystem 400 is mounted thereto.Overshot tool 420 also includes a pair ofhandles 427 that extend radially outward frombody 422 and enable ROVs to manipulate, rotate, andposition system 400 during subsea deployment. - Referring now to
FIGS. 15-17 ,hydrocarbon collection system 400 is shown being deployed subsea and positioned to capture hydrocarbons discharged fromexhaust conduit 335. More specifically, inFIG. 15 ,system 400 is shown being lowered subsea; inFIG. 16 ,system 400 is shown being moved laterally overoutlet end 335 b ofexhaust conduit 335; and inFIG. 17 ,system 400 is shown being advanced overoutlet end 335 b ofexhaust conduit 335 to capture hydrocarbons emitted therefrom. For subsea deployment and installation ofcollection system 400, one ormore ROVs 170 are preferably employed to aid inpositioning collection system 400 andmonitoring collection system 400,pressure control device 300,BOPs 120, and cappingstack 200. - Referring first to
FIG. 15 ,system 400 is coupled to the lower end of atubular string 700 at thesurface 102 with J-latch coupling 412, and is then controllably lowered subsea withstring 700. A derrick or other suitable device mounted to a surface vessel is preferably employed to support andlower system 400 onstring 700. - Using
string 700,system 400 is lowered subsea from a location generally above and laterally offset fromexhaust conduit 335. More specifically, during deployment,system 400 is preferably maintained outside ofplume 160 of hydrocarbon fluids emitted fromexhaust conduit 335. Loweringsystem 400 subsea inplume 160 may trigger the undesirable formation of hydrates withinsystem 400 and/orstring 700, particularly at elevations substantially abovesea floor 103 where the temperature of hydrocarbons inplume 160 is relatively low. Assystem 400 is lowered subsea, a hydrate inhibitor (e.g., methanol) may be injected intopipe 413 via asubsea ROV 170 and control panel 414. Any injected inhibitor is free to flow upward within the remainder ofsystem 400 andstring 700. In addition to injection of a hydrate inhibitor, or as an alternative thereto,string 700 can be filled with an inert gas such as nitrogen to help prevent the formation of hydrates therein during installation ofsystem 400. - Referring now to
FIGS. 15 and 16 ,system 400 is lowered laterally offset fromexhaust conduit 335 and outside ofplume 160 untilovershot tool 420 is slightly aboveoutlet end 335 b. Assystem 400 descends and approachesdevice 300,ROVs 170 monitor the position ofsystem 400 relative to cappingstack 200 anddevice 300. Next,system 400 is rotated and oriented to circumferentially alignconduit 335 withslot 423. - Moving now to
FIGS. 16 and 17 ,system 400 is moved laterally into position immediately aboveend 335 b withtool 420 substantially coaxially aligned withend 335 b. One ormore ROVs 170 may utilize theirclaws 172 and handles 427 to guide and rotatesystem 400 into proper alignment relative to exhaustconduit 335. - As best shown in
FIG. 17 , withovershot tool 420 positioned immediately aboveoutlet end 335 b, generally coaxially aligned withend 335 b, and withslot 423 circumferentially aligned withconduit 335,string 700 lowerssystem 400 axially downward, thereby inserting and axially advancingend 335 b ofexhaust conduit 335 intoovershot tool 420. As vertically orientedend 335 b axially advances into throughbore 421, the horizontal portion ofconduit 335 extends radially through and slidingly engagesslot 423.Conduit 335 is preferably advanced throughovershot tool 420 untilresilient bumpers 426 engageconduit 335 proximal upper end 422 a. - With
end 335 b sufficiently seated inovershot tool 420, hydrocarbon fluids discharged fromexhaust conduit 335 flow upward throughsystem 400 andstring 700 to the surface where they may be captured and contained. A hydrate inhibitor (e.g., methanol) may be injected intopipe 413 via control panel 414 whilesystem 400 is being lowered over the exhaust and/or during collection of discharged hydrocarbons to prevent and/or reduce the formation of hydrates within J-latch coupling 412 andstring 700. - During collection operations, the weight of
system 400 is supported bystring 700 to minimize the transfer of any loads to exhaustconduit 335 andpressure control device 300. Minimizing loads onexhaust conduit 335 as well as the flexibility ofconduit 430 ofcollection system 400 offers the potential to reduce the chances of inadvertentlydamaging conduit 335 and/orcontrol device 300, particularly if the deployment vessel at thesurface 102 experiences a sudden lateral or vertical movement. - Referring now to
FIGS. 18-20 , an embodiment of acollection system 500 for capturing hydrocarbon fluids exhausted from a subsea discharge site (e.g., hydrocarbons discharged from exhaust conduit 335) is shown. In this embodiment,system 500 includes aconnection member 510 and anovershot tool 520.Connection member 510 is hung from the lower end of a tubular string (e.g., string 700), and overshottool 520 is coupled to the discharge site and is slidingly received by theconnection member 510 subsea. - As best shown in
FIG. 19 ,connection member 510 has acentral axis 515, a first orupper end 510 a, a second orlower end 510 b oppositeend 510 a, and a central throughpassage 511 extending axially between ends 510 a, b. In this embodiment,connection member 510 includes a J-latch coupling 412 as previously described extending axially fromupper end 510 a and anelongate pipe 513 extending axially fromlower end 510 b to J-latch coupling 412. - Referring still to
FIG. 19 , J-latch coupling 412 comprises a rigidtubular body 416 having anannular funnel guide 417 atupper end 410 a and a pair of circumferentially spaced J-slots 418 positioned axiallyadjacent guide 417. Each J-slot 418 extends radially throughbody 416 topassage 511 and is configured to slidingly receive a pin on the lower end of a tubular string (e.g., drillstring) to releasablycouple connection member 510 to the tubular string for subsea deployment and manipulation -
Pipe 513 comprises a rigidtubular body 514 having a generallyrectangular funnel guide 516 atlower end 510 b and a pair ofhandles 517 axiallyadjacent guide 516.Handles 517 extend radially outward frombody 514 and enable ROVs to manipulate, rotate, andposition connection member 510 during subsea deployment. The upper end ofpipe 513 is coupled to the lower end of J-latch coupling 412 with a flex joint 518 that allowspipe 513 to pivot relative to J-latch coupling 412. An ROV control panel (e.g., ROV control panel 414) may be disposed alongpipe 513 axially below J-latch coupling 512 for injecting a hydrate inhibitors (e.g., methanol) intopipe 513 to reduce and/or prevent the formation of hydrates downstream ofpipe 513. - Referring now to
FIG. 20 , overshottool 520 has acentral axis 525, a first orupper end 520 a, a second orlower end 520 b oppositeend 520 a, and a central throughbore 521 extending axially between ends 520 a, b. In this embodiment, overshottool 520 includes acoupling member 522 atlower end 520 b and anelongate stabbing member 523 extending from couplingmember 522 toupper end 520 a. A flex joint (e.g., flex joint 518) can be provided betweenstabbing member 523 andcoupling member 522 if additional flexibility alongtool 520 is desired. Couplingmember 522 comprises a rigidtubular body 523, ahandle 524, and a plurality of circumferentially spaced lockingmembers 526. Handle 524 extends radially outward frombody 523 and enables ROVs to manipulate, rotate, and position overshottool 520 during subsea deployment. Lockingmembers 526 releasably secure overshottool 520 to the hydrocarbon discharge site (e.g., end 335 b of exhaust conduit 335). In this embodiment, three lockingmembers 526 uniformly spaced 90° apart are provided. Further, in this embodiment, each lockingmember 526 is a T-bolt that threadingly engages a mating bore extending radially throughbody 523. In particular, each lockingmember 526 has a first or radiallyouter end 526 a disposedoutside body 523 and a second or radially inner end (not shown) extending intobore 521. End 526 a of each lockingmember 526 is a T-handle that enables an ROV to rotate the corresponding lockingmember 526 to thread it radially inward and outward throughbody 523. -
Stabbing member 523 extends axially from couplingmember 522 and comprises a rigidtubular pipe 527 having an anglemule shoe tip 528 atupper end 520 a.Tip 528 facilities the axially insertion of stabbingmember 523 intofunnel guide 516 ofpipe 513 andpassage 511 atlower end 510 b. - Referring now to
FIGS. 21-25 ,hydrocarbon collection system 500 is shown being deployed subsea and positioned to capture hydrocarbons discharged fromexhaust conduit 335. More specifically, inFIG. 21 , overshottool 520 is shown being lowered subsea; inFIG. 22 , overshottool 520 is shown being positioned overoutlet end 335 b ofconduit 335; inFIG. 23 , overshottool 520 is shown being mounted toexhaust conduit 335; inFIG. 24 ,connection member 510 is shown being lowered subsea; inFIG. 25 ,connection member 510 is shown being moved laterally end 520 a ofovershot tool 520; and inFIG. 26 ,connection member 510 is shown being lowered and mounted toovershot tool 520. For subsea deployment and installation ofcollection system 500, one ormore ROVs 170 are preferably employed to aid in positioning ofovershot tool 520 andconnection member 510, as well as to monitorovershot tool 520,connection member 510,pressure control device 300,BOP 120, and cappingstack 200. - Referring first to
FIG. 21 , overshottool 520 is shown being controllably lowered subsea with awireline cable 180 releasably coupled totool 520 and extending to a surface vessel. A winch or crane mounted to a surface vessel is preferably employed to support andlower tool 520 oncables 180. - Using
cable 180, overshottool 520 is lowered subsea front a location generally above and laterally offset fromexhaust conduit 335 to maintainovershot tool 520 outside ofplume 160, thereby reducing the potential for the formation of hydrates therein.Overshot tool 520 is lowered laterally offsetfront exhaust conduit 335 and outside ofplume 160 untillower end 520 b is slightly aboveoutlet end 335 b. Astool 520 descends and approachesdevice 300,ROVs 170 monitor the position oftool 520 relative to cappingslack 200 anddevice 300. Moving now toFIG. 22 ,tool 520 is moved laterally into position immediately aboveend 335 b withtool 520 substantially coaxially aligned withend 335 b. One ormore ROVs 170 may utilize theirclaws 172 and handles 427 to guidetool 520 into proper alignment relative to exhaustconduit 335. - Referring now to
FIGS. 22 and 23 , withovershot tool 520 positioned immediately above and coaxially aligned withoutlet end 335 b,cable 180 lowerstool 520 axially downward, thereby inserting and axially advancingend 335 b ofexhaust conduit 335 intocoupling member 522. Withend 335 b sufficiently seated withinmember 522, one ormore ROVs 170 rotate lockingmembers 526 to threadingly advance the radially inner ends of locking members into engagement withexhaust conduit 335, thereby lockingovershot tool 520 ontoconduit 335. Withtool 520 mounted toconduit 335, the hydrocarbon fluids emitted atend 335 b flow upward throughbore 521 and outend 520 a. - Referring now to
FIG. 24 ,connection member 510 is coupled to the lower end of atubular string 700 at thesurface 102 with J-latch coupling 412, and is then controllably lowered subsea withstring 700. A derrick or other suitable device mounted to a surface vessel is preferably employed to support andlower device 300 onstring 700. Usingstring 700,connection member 510 is lowered subsea from a location generally above and laterally offset fromovershot tool 520 to maintainconnection member 510 outside ofplume 160, thereby reducing the potential for the formation of hydrates therein. -
Connection member 510 is lowered laterally offset fromovershot tool 520 and outside ofplume 160 untillower end 510 b is slightly abovetip 528 atupper end 520 a. Asconnection member 510 descends and approachesovershot tool 520,ROVs 170 monitor the position ofconnection member 510 relative totool 520, cappingstack 200, anddevice 300. Moving now toFIG. 25 ,connection member 510 is moved laterally into position immediately aboveend 520 a and substantially coaxially aligned with stabbingmember 523. One ormore ROVs 170 may utilize theirclaws 172 and handles 517 to guideconnection member 510 into proper alignment relative to stabbingmember 523. - Referring now to
FIGS. 25 and 26 , withconnection member 510 positioned immediately above and generally coaxially aligned with stabbingmember 523,string 700 lowersconnection member 510 axially downward, thereby inserting and axially advancingend 520 a ofovershot tool 520 intopassage 511 ofconnection member 510.Funnel guide 516 atend 510 b andmule shoe tip 528 atupper end 520 a facilitate the insertion and axial advancement of stabbingmember 523 intopipe 513 in theevent connection member 510 is slightly out of alignment with stabbingmember 523.Stabbing member 523 is axially advanced throughpipe 513 untiltip 528 is axially proximal and below flex joint 518, thereby allowing J-latch coupling 412 to pivot about flex joint 518 relative topipe 513 and stabbingmember 523 disposed therein. - With stabbing
member 523 disposed inpipe 513, hydrocarbon fluids discharged fromexhaust conduit 335 flow upward throughovershot tool 520,connection member 510, andstring 700 to the surface where they may be captured and contained. - During collection operations, the weight of
connection member 510 is supported bystring 700 to minimize the transfer of any loads toovershot tool 520,exhaust conduit 335, andpressure control device 300. Minimizing loads onexhaust conduit 335 as well as the flexibility ofconnection member 510 due to flex joint 518 offers the potential to reduce the chances of inadvertentlydamaging conduit 335 and/orcontrol device 300, particularly if the deployment vessel at thesurface 102 experiences a sudden lateral or vertical movement. - Referring now to
FIGS. 27 , an embodiment of acollection system 600 for capturing hydrocarbon fluids exhausted from a subsea discharge site (e.g., hydrocarbons discharged from exhaust conduit 335) is shown.System 600 has a central or longitudinal axis 605, a first orupper end 600 a, and a second orlower end 600 b oppositeend 600 a. In this embodiment,system 600 includes aconnection member 610 extending axially fromupper end 600 a, atop hat 620 coupled toconnection member 610, and an annularflexible skirt 630 extending fromtop hat 620 tolower end 600 b. -
Connection member 610 has a central axis 615 coincident with axis 605, a first orupper end 610 a definingupper end 600 a ofsystem 600, a second orlower end 610 b coupled totop hat 620, and a central throughbore 611 extending axially between ends 610 a, b. In this embodiment,connection member 610 includes a J-latch coupling 412 as previously described extending axially fromupper end 610 a. - Referring still to
FIG. 27 ,top hat 620 has a central axis 625 coaxially aligned with axis 615, a first orupper end 620 a coupled tolower end 610 b, and a second orlower end 620 b.Top hat 620 is an annular inverted funnel defining an inner flow passage extending betweenends 620 a, b. The flow passage has an inlet atlower end 620 b and an outlet atupper end 620 a in fluid communication withbore 611 ofconnection member 610. In this embodiment,top hat 620 also includes a plurality of circumferentially spacedauxiliary outlets 621 proximalupper end 620 a and anROV control panel 622. Eachoutlet 621 includes an ROV operatedvalve 623 that controls the flow of fluids through thecorresponding outlet 621.Control panel 622 includes a plurality of receptacles for injecting a hydrate inhibitor (e.g., methanol) intotop hat 620 to reduce and/or prevent the formation of hydrates withintop hat 620 and downstream oftop hat 620. A pair ofhandles 624 that extend radially fromtop hat 620 and enable ROVs to manipulate, rotate, and positiontop hat 620 during subsea deployment. Additional details and examples of top hats that may be used astop hat 620 are disclosed in U.S. Patent Application Ser. No. 61/384,358 filed Sep. 20, 2010 and entitled “Containment Cap for Controlling a Subsea Blowout,” which is hereby incorporated herein by reference in its entirety. -
Annular skirt 630 hangs fromlower end 620 b oftop hat 620. in this embodiment,skirt 630 comprises a plurality of flexible generallyrectangular panels 631 positioned circumferentially adjacent each other. More specifically, in this embodiment, eachpanel 631 is a rubber sheet having an axial length of four feet. - Referring now to
FIGS. 28-30 ,hydrocarbon collection system 600 is shown being deployed subsea and positioned to capture hydrocarbons discharged fromexhaust conduit 335. More specifically, inFIG. 28 ,system 600 is shown being lowered subsea; inFIG. 29 ,system 600 is shown being moved laterally overconduit 335; and inFIG. 30 ,system 600 is shown positioned aboutend 335 b ofexhaust conduit 335. For subsea deployment and installation ofcollection system 600, one ormore ROVs 170 are preferably employed to aid inpositioning collection system 600 andmonitoring collection system 600,pressure control device 300,BOP 120, and cappingstack 200. - Referring first to
FIG. 28 ,system 600 is coupled to the lower end of atubular string 700 at thesurface 102 with J-latch coupling 412, and is then controllably lowered subsea withstring 700. A derrick or other suitable device mounted to a surface vessel is preferably employed to support andlower system 600 onstring 700. - Using
string 700,system 600 is lowered subsea from a location generally above and laterally offset fromexhaust conduit 335 to maintainsystem 600 outside ofplume 160, thereby reducing the potential for the formation of hydrates therein. Assystem 600 is lowered subsea, a hydrate inhibitor (e.g., methanol) may be injected intotop hat 620 via a subsea.ROV 170 andcontrol panel 622. Any injected inhibitor is free to flow upward within the remainder ofsystem 600 andstring 700. - Referring now to
FIGS. 28-30 ,system 600 is lowered laterally offset fromexhaust conduit 335 and outside ofplume 160 untiloutlet end 335 b is axially positioned between ends 600 b, 620 b. Assystem 600 descends and approachesdevice 300,ROVs 170 monitor the position ofsystem 600 relative to cappingstack 200 anddevice 300. Next,system 600 is moved laterally to position end 335 b insideskirt 630. Assystem 600 moves laterally acrossend 335 b, circumferentially adjacentflexible panels 631 are urged apart to allowend 335 b to pass therebetween and intoskirt 630. One ormore ROVs 170 may utilize theirclaws 172 and handles 624 to guidesystem 600 as it is moved laterally acrossend 335 b. - With
end 335 b disposed withinskirt 630 and positioned axially between ends 600 b, 620 b, hydrocarbon fluids discharged fromexhaust conduit 335 flow upward throughskirt 630,top hat 620,connection member 610, andstring 700 to the surface where they may be captured and contained. A hydrate inhibitor (e.g., methanol) may be injected intotop hat 620 viacontrol panel 622 during collection of discharged hydrocarbons to prevent and/or reduce the formation of hydrates withintop hat 620,connection member 610, andstring 700. - During collection operations, the weight of
system 600 is supported bystring 700 to minimize the transfer of any loads to exhaustconduit 335 andpressure control device 300. Minimizing loads onexhaust conduit 335 as well as the flexibility ofconduit 430 ofcollection system 400 offers the potential to reduce the chances of inadvertentlydamaging conduit 335 and/orcontrol device 300, particularly if the deployment vessel at thesurface 102 experiences a sudden lateral or vertical movement. - In the manner described, embodiments of systems and methods described herein may be employed to contain and collect at least a portion of the hydrocarbon fluids exhausted from a subsea discharge site. Although embodiments of
system 400,system 500, andsystem 600 have been described as containing and collecting hydrocarbon fluids emitted frompressure control device 300 coupled toside outlet 214 of cappingstack 200, in general, embodiments described herein may be used to contain and collect hydrocarbons vented from any subsea discharge site including, without limitation, a subsea BOP or capping stack side outlet, a subsea manifold outlet, a subsea production tree outlet or leak, an outlet with an isolation valve operated locally by an ROV or operated remotely by a subsea control system, a normally closed outlet fitted with a pressure safety valve (e.g. relief valve), or a burst disc designed to open automatically if a pre-determined pressure differential is exceeded - 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 (23)
1. A method for capturing at least a portion of hydrocarbon fluids vented into the surrounding sea from a subsea discharge site the method comprising:
(a) mounting a pressure control device to the subsea discharge site;
(b) flowing the vented hydrocarbon fluids from the subsea discharge site through the pressure control device;
(c) positioning a collection system subsea on a lower end of a tubular string;
(d) flowing the vented hydrocarbons fluids from the pressure control device into the collection system and through the tubular string after (b); and
(e) minimizing lateral loads applied to the subsea discharge site by the collection system.
2. The method of claim 1 , wherein the discharge site is a side outlet of a capping stack coupled to a subsea BOP mounted to a wellhead disposed at the sea floor at an upper end of a wellbore.
3. The method of claim 1 , wherein the pressure control device includes a choke valve having an outlet in fluid communication with an exhaust conduit.
4. The method of claim 3 , wherein the pressure control device is releasably locked onto the discharge site.
5. The method of claim 1 , wherein the collection system comprises:
a connection member disposed at an upper end of the collection system;
an overshot tool disposed at a lower end of the collection system; and
a flexible conduit extending from the connection member to the overshot tool.
6. The method of claim 5 , wherein the overshot tool comprises a rigid tubular having a central axis, a lower end, and an elongate slot extending axially from the lower end.
7. The method of claim 5 , wherein the pressure control device includes a choke valve having an outlet in fluid communication with an exhaust conduit;
wherein (c) further comprises:
(c1) inserting an outlet end of exhaust conduit into the lower end of the overshot tool;
(c2) axially advancing the outlet end of the exhaust conduit into the overshot tool; and
(c3) axially advancing the exhaust conduit through the slot during (c2);
wherein (d) comprises flowing the vented hydrocarbons fluids from the exhaust conduit through the connection member, the flexible conduit, and the connection member into the tubular string.
8. The method of claim 1 , wherein the collection system comprises:
an overshot tool having a lower end comprising a coupling member and an upper end comprising a stabbing member; and
a connection member hung from a lower end of the tubular string and configured to receive the stabbing member of the overshot tool.
9. The method of claim 8 , wherein the pressure control device includes a choke valve having an outlet in fluid communication with an exhaust conduit;
wherein (c) further comprises:
(c1) positioning the overshot tool subsea;
(c2) inserting an outlet end of exhaust conduit into the coupling member of the overshot tool;
(c3) releasably securing the coupling member to the exhaust conduit
(c4) positioning the connection member subsea with the tubular string;
(c5) inserting the stabbing member of the overshot tool into a lower end of the connection member after (c3); and
(c6) axially advancing the stabbing member into the connection member after (c4);
wherein (d) comprises flowing the vented hydrocarbons fluids from the exhaust conduit through the overshot tool and the connection member into the tubular string.
10. The method of claim 1 , wherein the collection system comprises:
a connection member hung from a lower end of the tubular string;
a top hat coupled to the connection member;
an annular skirt hung from a lower end of the top hat, wherein the skirt includes a plurality of circumferentially adjacent flexible panels.
11. The method of claim 10 , wherein the pressure control device includes a choke valve having an outlet in fluid communication with an exhaust conduit;
wherein (c) further comprises:
(c1) positioning the collection system subsea laterally offset from the exhaust conduit;
(c2) positioning the collection system subsea until an upper end of the exhaust conduit is axially positioned between the top hat and a lower end of the skirt;
(c3) moving the collection system laterally over the upper end of the exhaust conduit;
(c4) pushing the flexible panels apart with the upper end of the exhaust conduit during (c3);
(c5) positioning the upper end of the exhaust conduit within the skirt;
wherein (d) comprises flowing the vented hydrocarbons fluids from the exhaust conduit through the top hat and the connection member into the tubular string.
12. An assembly for capturing at least a portion of hydrocarbon fluids vented into the surrounding sea from a subsea discharge site, the assembly comprising:
a collection system including a connection member, an overshot tool, and a flexible conduit extending from the overshot tool to the connection member;
wherein the connection member has a central axis, an upper end, a lower end, and a flow passage extending axially from the upper end to the lower end, the upper end configured to releasably connect to a lower end of a tubular string and the lower end coupled to the flexible conduit;
wherein the overshot tool has a central axis, an upper end coupled to the flexible conduit, a lower end, and a flow passage extending from the lower end of the overshot tool to the upper end of the overshot tool;
wherein the overshot tool includes an elongate slot extending axially from the lower end and extending radially through the overshot tool to the flow passage of the overshot tool;
wherein the flexible conduit is in fluid communication with the flow passage of the overshot tool and the flow passage of the connection member.
13. The assembly of claim 12 , wherein the connection member comprises a J-latch coupling having a rigid tubular body, an annular funnel guide at the upper end of the connection member, and a pair of circumferentially spaced J-slots in the e tubular body axially adjacent the funnel guide.
14. The assembly of claim 12 , wherein the slot of the overshot tool defines a pair of opposed edges, wherein a resilient bumper is mounted to at least a portion of each edge.
15. The assembly of claim 12 , further comprising a pressure control device coupled to the discharge site, wherein the pressure control device includes a choke valve having an outlet in fluid communication with an exhaust conduit;
wherein the exhaust conduit extends through the slot in the overshot tool, and wherein an outlet end of the exhaust conduit is disposed within the overshot tool.
16. The assembly of claim 15 , wherein the pressure control device has a central axis, an upper end, and a lower end;
wherein the pressure control device comprises:
an annular receiving guide at the lower end of the pressure control device;
a coupling axially adjacent the receiving guide, wherein the coupling is configured to releasably lock onto the discharge site;
a tubular fluid conduit extending from the coupling of the pressure control device to an inlet of the choke valve.
17. The assembly of claim 15 , wherein the coupling of the pressure control device is configured to releasably lock onto a side outlet of a capping stack mounted to a subsea BOP.
18. An assembly for capturing at least a portion of hydrocarbon fluids vented into the surrounding sea from a subsea discharge site, the assembly comprising:
a collection system including a connection member and an overshot tool;
wherein the connection member has a central axis, an upper end, a lower end, and a flow passage extending axially from the upper end to the lower end, the upper end configured to releasably connect to a lower end of a tubular string and the lower end comprising a funnel guide;
wherein the overshot tool has a central axis, an upper end, a lower end, a flow passage extending from the lower end of the overshot tool to the upper end of the overshot tool;
wherein the overshot tool includes a coupling member at the lower end of the overshot tool and an elongate stabbing member extending axially from the coupling member to the upper end of the overshot tool;
wherein the stabbing member is slidingly disposed in lire flow passage of lire connection member.
19. The assembly of claim 18 , wherein the connection member comprises a J-latch coupling having a rigid tubular body, an annular funnel guide at the upper end of the connection member, and a pair of circumferentially spaced J-slots in the tubular body axially adjacent the funnel guide.
20. The assembly of claim 18 , wherein the coupling member includes a plurality of circumferentially spaced locking members, wherein each locking member threadingly engages a bore extending radially through the coupling member and has a first end disposed within the flow passage of the overshot tool and a second end external the coupling member.
21. The assembly of claim 18 , further comprising a pressure control device coupled to the discharge site, wherein the pressure control device includes a choke valve having an outlet in fluid communication with an exhaust conduit;
wherein the outlet end of the exhaust conduit is disposed within the coupling member;
wherein the first end of each locking member engages the exhaust conduit.
22. The assembly of claim 21 , wherein the pressure control device has a central axis, an upper end, and a lower end;
wherein the pressure control device comprises:
an annular receiving guide at the lower end of the pressure control device;
a coupling axially adjacent the receiving guide, wherein the coupling is configured to releasably lock onto the discharge site;
a tubular fluid conduit extending from the coupling of the pressure control device to an inlet of the choke valve.
23. The assembly of claim 22 , wherein the coupling of the pressure control device is configured to releasably lock onto a side outlet of a capping stack mounted to a subsea BOP.
Priority Applications (1)
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US13/673,365 US20130140035A1 (en) | 2011-11-11 | 2012-11-09 | Systems And Methods For Collecting Hydrocarbons Vented From A Subsea Discharge Site |
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US201161558827P | 2011-11-11 | 2011-11-11 | |
US13/673,365 US20130140035A1 (en) | 2011-11-11 | 2012-11-09 | Systems And Methods For Collecting Hydrocarbons Vented From A Subsea Discharge Site |
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US20130140035A1 true US20130140035A1 (en) | 2013-06-06 |
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US13/673,365 Abandoned US20130140035A1 (en) | 2011-11-11 | 2012-11-09 | Systems And Methods For Collecting Hydrocarbons Vented From A Subsea Discharge Site |
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WO (1) | WO2013071081A2 (en) |
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US20140144646A1 (en) * | 2012-11-28 | 2014-05-29 | Stena Drilling Ltd. | Well Safety Equipment |
US20160059944A1 (en) * | 2014-09-03 | 2016-03-03 | Conocophillips Company | Subsea system for seabed operations |
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Also Published As
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WO2013071081A3 (en) | 2014-05-30 |
WO2013071081A2 (en) | 2013-05-16 |
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