CA2602069C - An apparatus and a method for deployment of a well intervention tool string into a subsea well - Google Patents
An apparatus and a method for deployment of a well intervention tool string into a subsea well Download PDFInfo
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- CA2602069C CA2602069C CA2602069A CA2602069A CA2602069C CA 2602069 C CA2602069 C CA 2602069C CA 2602069 A CA2602069 A CA 2602069A CA 2602069 A CA2602069 A CA 2602069A CA 2602069 C CA2602069 C CA 2602069C
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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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
- E21B33/076—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
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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
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/14—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells for displacing a cable or cable-operated tool, e.g. for logging or perforating operations in deviated wells
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
Abstract
The present invention regards an apparatus and a method for subsea deployment and/or intervention through a wellhead (102) of a petroleum well (112). The apparatus comprises a first module (101) integrated in a portion of a subsea well intervention system assembly (102, 103) and/or a subsea production system assembly, the first module (101) comprising an intervention tool bore (201); a second module (301) comprising a tubular element (302) initially housing an intervention tool (314), wherein the second module (301) being arranged for sliding into releasable engagement with the intervention tool bore (201) of the first module (101), whereupon the intervention tool (314) is arranged for disengagement from the tubular element (302) for deployment of the intervention tool (314) into the wellbore (112).
Description
AN APPARATUS AND A METHOD FOR DEPLOYMENT OF A WELL INTER-VENTION TOOL STRING INTO A SUBSEA WELL.
This invention relates to an apparatus and a method for deployment of a well intervention tool string into a sub-sea well associated with the production of hydrocarbons.
Numerous of today's wells related to the production of hy-drocarbons are subsea wells, meaning that significant parts of the production hardware such as wellheads, valve arrangements, instrumentation, control systems, production manifolds and other accessories are located on the seabed.
Subsea field developments are common in the oil industry today. This field development philosophy enables a low capital expense for the initial field development compared to for example a platform solution. Hence, subsea pro-duction systems have enabled the development of small fields, remote locations, deep water areas and other fields where traditional platform solutions have been non-feasible due to high costs.
As they have matured, a significant operational expense problem has emerged for the subsea fields: Well mainte-nance/service is very expensive compared to platform wells.
Well maintenance and service comprises a range of methods for deploying relevant tool strings into live wells in or-der to do work. Traditional methods for deploying/inter-vening relevant tools into live wells comprise wireline, coil tubing, and snubbing. The downhole tools that can be intervened and applied using such methods include perfo-ration guns, zone isolation devices, data recording tools, fluid samplers, a range of mechanical tools and other de-vices.
Maintenance from a platform involves rigging up the requi-red equipment (for instance wireline or coil tubing) on an appropriate deck space. Hence, the costs of maintenance are limited to renting/acquiring the equipment that is di-rectly related to the operation of interest.
On subsea wells, a drilling rig or an intervention vessel must be mobilised in order to do the same work. Hence, rental costs for the rig/vessel comes on top of the cost of renting the intervention service (wireline/coil tubing) itself. This means that maintaining a subsea well is tre-mendously more expensive, typically ten times or more, than maintaining a platform well.
There has been a large industrial focus on applying tai-lor-made vessels, typically boats, for the purpose of sub-sea well intervention. These have a somewhat lower cost than a drilling rig.
For intervention or maintenance operations to be performed on a live well, lubricator systems are utilised in order to get tools in and out of the well in a controlled man-ner. Typically, a lubricator system comprises the follow-ing:
= A tree connector. This is the interface between the wellhead and the lubricator stack.
= Valve housings, so-called BOP's (blow out prevent-ers). These include (gate-shaped) valves, that can cut cable and coil tubing and thereupon form a seal against the live well, as well as valves that can close around the cable/coil tubing, without damaging ~ this, and form a seal against the well pressure.
This invention relates to an apparatus and a method for deployment of a well intervention tool string into a sub-sea well associated with the production of hydrocarbons.
Numerous of today's wells related to the production of hy-drocarbons are subsea wells, meaning that significant parts of the production hardware such as wellheads, valve arrangements, instrumentation, control systems, production manifolds and other accessories are located on the seabed.
Subsea field developments are common in the oil industry today. This field development philosophy enables a low capital expense for the initial field development compared to for example a platform solution. Hence, subsea pro-duction systems have enabled the development of small fields, remote locations, deep water areas and other fields where traditional platform solutions have been non-feasible due to high costs.
As they have matured, a significant operational expense problem has emerged for the subsea fields: Well mainte-nance/service is very expensive compared to platform wells.
Well maintenance and service comprises a range of methods for deploying relevant tool strings into live wells in or-der to do work. Traditional methods for deploying/inter-vening relevant tools into live wells comprise wireline, coil tubing, and snubbing. The downhole tools that can be intervened and applied using such methods include perfo-ration guns, zone isolation devices, data recording tools, fluid samplers, a range of mechanical tools and other de-vices.
Maintenance from a platform involves rigging up the requi-red equipment (for instance wireline or coil tubing) on an appropriate deck space. Hence, the costs of maintenance are limited to renting/acquiring the equipment that is di-rectly related to the operation of interest.
On subsea wells, a drilling rig or an intervention vessel must be mobilised in order to do the same work. Hence, rental costs for the rig/vessel comes on top of the cost of renting the intervention service (wireline/coil tubing) itself. This means that maintaining a subsea well is tre-mendously more expensive, typically ten times or more, than maintaining a platform well.
There has been a large industrial focus on applying tai-lor-made vessels, typically boats, for the purpose of sub-sea well intervention. These have a somewhat lower cost than a drilling rig.
For intervention or maintenance operations to be performed on a live well, lubricator systems are utilised in order to get tools in and out of the well in a controlled man-ner. Typically, a lubricator system comprises the follow-ing:
= A tree connector. This is the interface between the wellhead and the lubricator stack.
= Valve housings, so-called BOP's (blow out prevent-ers). These include (gate-shaped) valves, that can cut cable and coil tubing and thereupon form a seal against the live well, as well as valves that can close around the cable/coil tubing, without damaging ~ this, and form a seal against the well pressure.
= Riser sections. This is simply spacer pipe. The accu-mulated length of the riser and BOP determines the length of tool string that can be intervened into the well in one.run.
= Top seal assembly. In order to run a cable or a coil tubing in and out of a well environment, a system that seals between the high-pressurised well environ-ment and the atmospheric (for surface operations) or seabed pressure (for subsea operations) conditions on the outside of the lubricator, is needed.
o For coil tubing operations, so-called stripper rubbers, that are ring-shaped moulds of an elas-tomer material, nylon, Teflon or similar are used. Stripper rubbers are commonly split in two for mounting purposes and access during the ope-ration.
o Annular bags can also be utilised for coil tub-ing operations. These are ring-shaped, elas-tomer-based barrier systems. Rubber elements are inflated around the coil in order to create a seal against it. Annular bags are also commonly used for heavier pipe operations, such as drill-ing. A major difference between the stripper rubber and the annular bag is the latter's abil-ity to seal against objects/pipe of various di-ameter.
o For slick wireline (slickline) analogues to the stripper rubbers may be used, so-called stuffing boxes, which is a stack of elastomer packers that seal around the wire.
o In order to intervene with a braided cable into a well, a so-called grease injection head (GIH) is required. By means of long, narrow pipes (flow tubes) and an injection system using vis-cous grease, the pressure differential between the well and the atmosphere is overcome and a braided cable intervention can be performed.
= Top seal assembly. In order to run a cable or a coil tubing in and out of a well environment, a system that seals between the high-pressurised well environ-ment and the atmospheric (for surface operations) or seabed pressure (for subsea operations) conditions on the outside of the lubricator, is needed.
o For coil tubing operations, so-called stripper rubbers, that are ring-shaped moulds of an elas-tomer material, nylon, Teflon or similar are used. Stripper rubbers are commonly split in two for mounting purposes and access during the ope-ration.
o Annular bags can also be utilised for coil tub-ing operations. These are ring-shaped, elas-tomer-based barrier systems. Rubber elements are inflated around the coil in order to create a seal against it. Annular bags are also commonly used for heavier pipe operations, such as drill-ing. A major difference between the stripper rubber and the annular bag is the latter's abil-ity to seal against objects/pipe of various di-ameter.
o For slick wireline (slickline) analogues to the stripper rubbers may be used, so-called stuffing boxes, which is a stack of elastomer packers that seal around the wire.
o In order to intervene with a braided cable into a well, a so-called grease injection head (GIH) is required. By means of long, narrow pipes (flow tubes) and an injection system using vis-cous grease, the pressure differential between the well and the atmosphere is overcome and a braided cable intervention can be performed.
A lubricator ensures that barrier requirements are com-plied with during all stages of the well intervention op-eration. This means that new barriers (between the high-pressurised well fluid and the open environment) are es-tablished before old barriers are removed. As an example, a typical well intervention operation involves the follow-ing steps:
= Assembly of the lubricator system and mounting of this onto the welihead;
= Mounting of the tool string inside the lubricator;
= Closing of the lubricator with the tool string inside of it;
= Filling the lubricator with a liquid, for example gly-col;
= Pressure testing the lubricator (upon doing this a new barrier has been established and verified);
= Alignment of the lubricator pressure to equal the well-head pressure;
= Opening of the wellhead valves (i.e. the original bar-rier is removed);
= Intervene the tool string into the well to do the re-quired operation;
When bringing tools out of the well, reversed procedures similar to the one above are used to ensure that the original barriers (the wellhead valves) are re-established (closed) before opening the lubricator to take out/replace the tool string.
In relation to the development of subsea intervention ves-sels (boats), associated subsea lubricator assemblies are developed.
As of current, such subsea lubricator systems have been analogues to lubricator systems for surface/platform op-erations, as described in the previous section. Hence, a subsea lubricator system, common of today, is simply a "marinated" surface lubricator system, by means of adding features that compensate for the fact that there is a ma-rine environment on the outside of the lubricator rather that atmospheric air.
Subsea lubricators as of today are limited by several fac-tors.
There are height limitations in that the lubricator can not exceed a certain height. This is related to technical as well as economical considerations. For instance, in-creaseing height means increasing bending momentum at the base of the subsea stack where the lubricator is anchored to the subsea wellhead. The latter has been a significant challenge and limitation with today's lubricators. Also, should the lubricator become too high, big and bulky, this would impose additional requirements to the vessel, which again could make the operation exceed accepted economical limits.
The height restriction imposes direct limitations to tool string length. With current subsea lubricator systems and methods, the wellhead valves can not be opened prior to having connected, closed, performed fluid displacement, and pressure tested the lubricator itself. Hence, the cur-rent lubricator technology becomes the limiting factor with respect to tool string length. This again means that operations requiring long tool strings must be performed in several smaller steps. Such steps may drag the opera-tion out in time and increase the costs dramatically. In worst case, operations are not initiated as they become non-economical.
As of today, the length of tool string that can be inter-vened in one run is limited to approximately 20 metres.
There exist lubricator concepts that apply telescopic joints in order to lengthen the lubricator. Typically, such telescopic joints are elongated downwards through the open wellhead, hence a lengthening of lubricator space by a factor close to 100%, compared to standard subsea lubri-cator systems, can be achieved.
= Assembly of the lubricator system and mounting of this onto the welihead;
= Mounting of the tool string inside the lubricator;
= Closing of the lubricator with the tool string inside of it;
= Filling the lubricator with a liquid, for example gly-col;
= Pressure testing the lubricator (upon doing this a new barrier has been established and verified);
= Alignment of the lubricator pressure to equal the well-head pressure;
= Opening of the wellhead valves (i.e. the original bar-rier is removed);
= Intervene the tool string into the well to do the re-quired operation;
When bringing tools out of the well, reversed procedures similar to the one above are used to ensure that the original barriers (the wellhead valves) are re-established (closed) before opening the lubricator to take out/replace the tool string.
In relation to the development of subsea intervention ves-sels (boats), associated subsea lubricator assemblies are developed.
As of current, such subsea lubricator systems have been analogues to lubricator systems for surface/platform op-erations, as described in the previous section. Hence, a subsea lubricator system, common of today, is simply a "marinated" surface lubricator system, by means of adding features that compensate for the fact that there is a ma-rine environment on the outside of the lubricator rather that atmospheric air.
Subsea lubricators as of today are limited by several fac-tors.
There are height limitations in that the lubricator can not exceed a certain height. This is related to technical as well as economical considerations. For instance, in-creaseing height means increasing bending momentum at the base of the subsea stack where the lubricator is anchored to the subsea wellhead. The latter has been a significant challenge and limitation with today's lubricators. Also, should the lubricator become too high, big and bulky, this would impose additional requirements to the vessel, which again could make the operation exceed accepted economical limits.
The height restriction imposes direct limitations to tool string length. With current subsea lubricator systems and methods, the wellhead valves can not be opened prior to having connected, closed, performed fluid displacement, and pressure tested the lubricator itself. Hence, the cur-rent lubricator technology becomes the limiting factor with respect to tool string length. This again means that operations requiring long tool strings must be performed in several smaller steps. Such steps may drag the opera-tion out in time and increase the costs dramatically. In worst case, operations are not initiated as they become non-economical.
As of today, the length of tool string that can be inter-vened in one run is limited to approximately 20 metres.
There exist lubricator concepts that apply telescopic joints in order to lengthen the lubricator. Typically, such telescopic joints are elongated downwards through the open wellhead, hence a lengthening of lubricator space by a factor close to 100%, compared to standard subsea lubri-cator systems, can be achieved.
For platform operations, there exists a deployment system that allows a tool string to be deployed through an open wellhead, and where the downhole safety valve (DHSV) is the only barrier when bringing tools in and out of the top section of the well. The aim with this technology has been to:
= Run (very) long tool strings into a live well = Reduce the height of the traditional lubricator stack = Enable operations in wellhead areas with height re-strictions When using this technology, pressure is bled down above a closed down hole safety valve, DHSV, and the tools are brought into the well through a "wide open wellhead". Upon getting the tools in place, the top seal assembly (for ex-ample a grease injection head) is mounted on top of the lubricator stack, before the DHSV is opened and the tools are run to the lower sections of the well to do the work.
Here, the lubricator stack and its functions are not re-moved, but the riser section is, and thereby the main com-ponent that contributes to height. By means of system fea-tures that guarantee that no object can fall into the well and damage the DHSV during rig-up, it is allowed to oper-ate against only one barrier in certain stages of the op-eration.
Such platform deployment systems are not applicable on subsea wells as they cannot handle the pollution problem-atic: Well fluids that are present above the downhole safety valve would tend to segregate upwards and pollute the sea because the well fluids are lighter than the sea water.
The invention has as its object to remedy, or at least re-duce, one or more drawbacks of the prior art.
The object is realized through features which are speci-fied in the description below and in the following Claims.
= Run (very) long tool strings into a live well = Reduce the height of the traditional lubricator stack = Enable operations in wellhead areas with height re-strictions When using this technology, pressure is bled down above a closed down hole safety valve, DHSV, and the tools are brought into the well through a "wide open wellhead". Upon getting the tools in place, the top seal assembly (for ex-ample a grease injection head) is mounted on top of the lubricator stack, before the DHSV is opened and the tools are run to the lower sections of the well to do the work.
Here, the lubricator stack and its functions are not re-moved, but the riser section is, and thereby the main com-ponent that contributes to height. By means of system fea-tures that guarantee that no object can fall into the well and damage the DHSV during rig-up, it is allowed to oper-ate against only one barrier in certain stages of the op-eration.
Such platform deployment systems are not applicable on subsea wells as they cannot handle the pollution problem-atic: Well fluids that are present above the downhole safety valve would tend to segregate upwards and pollute the sea because the well fluids are lighter than the sea water.
The invention has as its object to remedy, or at least re-duce, one or more drawbacks of the prior art.
The object is realized through features which are speci-fied in the description below and in the following Claims.
Tt is an object of the present invention to provide an ap-paratus for subsea intervention that reduce costs and op-erational complexity.
A further object of the present invention is to provide a method for utilising the apparatus according to the inven-tion.
The invention aims at reducing lubricator height and, at the same time, dramatically increasing the length of tool string that can be intervened in one operational step.
The invention comprises a subsea deployment system and a method for conducting intervention. The subsea deployment system comprises two main modules, a first module that at-taches to the subsea wellhead and/or lubricator assembly, and a second module that attaches to the tool string to be intervened. More specifically, the first module of the in-vention comprises a subsea deployment lubricator module hereinafter denoted as "SDLM", which is a system com-ponent, or stack of system components, that forms part of a subsea lubricator. The second module of the invention comprises a subsea deployment intervention module herein-after denoted as "SDIM" which attaches to the tool string to be intervened. The two system modules interface and in-teract in a manner that enables deployment of long tool strings into wells, with a minimal height subsea lubrica-tor stack.
The main consequential differences between the invention and existing subsea lubricator systems are:
= Eliminated/reduced need for riser joints in the lu-bricator section, as the tool string is deployed "through the open subsea wellhead" by means of a unique subsea deployment technique.
= Capability to deploy almost unlimited length of tool strings in one run (the upper theoretical limit is given by the distance from the wellhead to the down-hole safety valve).
A further object of the present invention is to provide a method for utilising the apparatus according to the inven-tion.
The invention aims at reducing lubricator height and, at the same time, dramatically increasing the length of tool string that can be intervened in one operational step.
The invention comprises a subsea deployment system and a method for conducting intervention. The subsea deployment system comprises two main modules, a first module that at-taches to the subsea wellhead and/or lubricator assembly, and a second module that attaches to the tool string to be intervened. More specifically, the first module of the in-vention comprises a subsea deployment lubricator module hereinafter denoted as "SDLM", which is a system com-ponent, or stack of system components, that forms part of a subsea lubricator. The second module of the invention comprises a subsea deployment intervention module herein-after denoted as "SDIM" which attaches to the tool string to be intervened. The two system modules interface and in-teract in a manner that enables deployment of long tool strings into wells, with a minimal height subsea lubrica-tor stack.
The main consequential differences between the invention and existing subsea lubricator systems are:
= Eliminated/reduced need for riser joints in the lu-bricator section, as the tool string is deployed "through the open subsea wellhead" by means of a unique subsea deployment technique.
= Capability to deploy almost unlimited length of tool strings in one run (the upper theoretical limit is given by the distance from the wellhead to the down-hole safety valve).
The main difference from deployment systems for sur-face/platform applications is a set of novel system compo-nents and techniques that ensure a seal to be present be-tween the well and the outer environment (the sea) during deployment, hence well fluids cannot escape during the de-ployment operation.
The SDLM is the "lubricator part" of the subsea deployment system. In one embodiment of the invention, the lower end of the SDLM is attached to the wellhead and the upper end attached to a BOP (Blow Out Preventer) module. In another embodiment of the invention, the lower end of the SDLM is attached to the wellhead indirectly, by means of an inter-face module, a LRP (Lower Riser Package) or other similar equipment.
The SDLM comprises a main bore, preferably provided in the centre region, and normally of similar or larger inner di-ameter than the wellbore itself.
The SDLM comprises a seal arrangement. In one aspect of the invention the seal is a dynamic seal. In one embodi-ment, this is a stripper rubber made of elastomer, nylon, Teflon or similar material. By applying radial or axial forces, the seal arrangement according to said aspect is forced radial inwards to seal around any matching object that is inserted in the bore of the SDLM. In another em-bodiment of the invention, the seal arrangement is an an-nular bag or similar system that inflates around objects in the centre of the SDLM.
In one embodiment of the invention, the seal arrangement comprises one of said two sealing elements. In another em-bodiment of the invention, the seal arrangement comprises a stack of multiple amounts and/or types of sealing ele-ments. In one embodiment of the invention, some of the seals in a stack serve the purpose as a well barrier, whereas other serves the purpose as "vipers" in order to prevent pollution to the sea. In one embodiment of the in-vention, only the "vipers" are fully active during normal operation, whereas the other sealing arrangements are ac-tivated in the case of emergency.
The SDLM is the "lubricator part" of the subsea deployment system. In one embodiment of the invention, the lower end of the SDLM is attached to the wellhead and the upper end attached to a BOP (Blow Out Preventer) module. In another embodiment of the invention, the lower end of the SDLM is attached to the wellhead indirectly, by means of an inter-face module, a LRP (Lower Riser Package) or other similar equipment.
The SDLM comprises a main bore, preferably provided in the centre region, and normally of similar or larger inner di-ameter than the wellbore itself.
The SDLM comprises a seal arrangement. In one aspect of the invention the seal is a dynamic seal. In one embodi-ment, this is a stripper rubber made of elastomer, nylon, Teflon or similar material. By applying radial or axial forces, the seal arrangement according to said aspect is forced radial inwards to seal around any matching object that is inserted in the bore of the SDLM. In another em-bodiment of the invention, the seal arrangement is an an-nular bag or similar system that inflates around objects in the centre of the SDLM.
In one embodiment of the invention, the seal arrangement comprises one of said two sealing elements. In another em-bodiment of the invention, the seal arrangement comprises a stack of multiple amounts and/or types of sealing ele-ments. In one embodiment of the invention, some of the seals in a stack serve the purpose as a well barrier, whereas other serves the purpose as "vipers" in order to prevent pollution to the sea. In one embodiment of the in-vention, only the "vipers" are fully active during normal operation, whereas the other sealing arrangements are ac-tivated in the case of emergency.
The SDLM also comprises a valve assembly. This serves the purpose to prevent upward segregating fluids from the well to pollute the marine environment in parts of the opera-tional sequence. Also, the valve assembly serves the pur-pose of providing a barrier against the well during cer-tain operational stages, and to provide means for pressure testing against, in order to verify seal integrity.
In a preferred embodiment of the invention, the valve as-sembly includes a double set of flapper type valves, where the upper is a tri-arm flapper and the lower is a con-ventional flapper valve. In one embodiment of the invent-ion, the upper tri-arm flapper valve opens by means of forcing the intervention string assembly into it whereupon the lower flapper automatically opens as the two valves are mechanically hinged. Hence, the lower valve may be able to contain elastomer seals, sealing surfaces and other features that should not be exposed to mechanical contact with the intervention string. In summary, for this embodiment, the upper tri-arm flapper is to be considered a mechanical activation mechanism for the lower flapper that is the real barrier/sealing mechanism towards the wellbore. In one embodiment of the invention, the valve/
valve assembly is spring-loaded and biases towards a closed position. In this case, should the intervention string be retrieved out of the valve assembly, the valves will automatically close.
In one embodiment of the invention, the above described valves are complemented with another valve, typically a ball- or a gate valve, located below the other valves.
This valve enables pressure testing of seal integrity at the time of stinging the tool string assembly into the SDLM. In another embodiment of the invention, this latter valve fully replaces the need for one or both of the de-scribed flapper valves and is the only valve that is re-quired for the described purposes.
In other embodiments of the invention, the valve assembly includes or comprises alternative valve types, such as ball valves, gate valves and other valves as well as a combination of such type valves. These valves could be op-erated mechanically, electrically, hydraulically or by means of other relevant forces, using intervention tools or surface operated electrical, hydraulic or other surface operation mechanisms connected to the subsea mounted equipment. Also, wireless activation signals could be ap-plied to activate the valves.
In one embodiment of the invention, the SDLM comprises an anti-blowout system. In one embodiment of the invention, this is a device that is pre-installed and is centered in the bore of the SDLM, an anti-blowout sub, which attaches to the intervention string assembly during deployment. The anti-blowout sub has an OD that is larger than the ID of the SDLM above the hang-off point of the anti-blowout sub.
Hence, the intervention string can not be blown out of the well.
In one embodiment of the invention, the anti-blowout sub and the matching anti-blowout profile in the SDLM have the shape and characteristics of a dampener. In one embodiment of the invention, the two components form the male and fe-male of a hydraulic dampener, where fluid becomes trapped between the anti-blowout sub and the anti-blowout profile of the SDLM, and the said fluid only can escape via narrow channels that reduce in size or number the more fluid that is displaced. Hence, a gradual dampening pattern is achieved in order to avoid system damage due to hard im-pacts between the anti-blow-out sub and the SDLM. In other embodiments of the invention, the dampener mechanism is based on other known dampener principles such as springs, friction dampeners and other.
In another embodiment of the invention, the anti-blowout function is handled by means of a gripping/locking system that prevents upward movement of the intervention string assembly. In one embodiment of the invention, upward move-ment of the intervention string assembly directly mechani-cally activates the gripping/locking system. In another embodiment of the invention, the gripping/locking system is activated by means of sensors detecting unwanted situ-ations (leakage, kick, blowout, unexpected upward movement of the intervention string assembly). Such sensors could include detection devices for motion, position, pressure, fluid flowrate, fluid composition, volumetric changes and other. In one embodiment of the invention, the grip-ping/locking system is operator activated. In another em-bodiment of the invention, the gripping/locking system comprises a combination of some or all of the herein men-tioned activation features.
In one embodiment of the invention, the gripping/locking system includes slips that slide gently along the inter-vention string assembly while this is being deployed into the well, but makes a firm grip at the instant this starts to move upwards. For deploying out of the well, the slips are foreseen retrieved/removed radial to some distance away from the intervention string assembly in order to de-ploy this out of the well (i.e. upward movement), but linked, in a fail-safe mode, to a release mechanism that activate the slips and make them grip the intervention string assembly in case an un-wanted event (e.g. a blow-out, a kick or similar) should take place. Such an un-wanted event could be indicated by means of monitoring the speed of the upward movement of the intervention string assembly, the fluid displacement into the well during de-ployment out, acceleration or other indicators of unwanted events, or a combination of such.
In one embodiment of the invention, the gripping/locking feature is ensured by means of operator activation of the annular bag that in one embodiment forms part of the seal arrangement of the SDLM. Here, the annular bag is not fully inflated against the intervention string assembly during normal operations, but only so in the case of an emergency.
In a preferred embodiment of the invention, the SDLM com-prises flushing systems in order to remove unwanted fluids from contained spaces before opening access to the well, to the open environment, to flowlines or similar. zn one embodiment of the invention, flushing lines are run and operated from the vessel used for the subsea intervention operation. In another embodiment of the invention, dedi-cated vessels/tanks and pump systems are used for flushing purposes.
In one embodiment of the invention, the SDLM and acces-sories comprises design and system to avoid fluids being trapped in contained spaces, which can prevent system functionality.
In a preferred embodiment of the invention, the SDLM and accessories comprises means for pressure testing and moni-toring of such during all relevant operational stages.
In a preferred embodiment of the invention, the SDLM and accessories comprises means for monitoring of operational parameters such as pressure, temperature, fluid flow rate, volume displacement and fluid properties during all stages of the operation. In a preferred embodiment of the inven-tion, the SDLM comprise a position indicator system that corresponds with the intervention string assembly.
In a preferred embodiment of the invention, the SDLM com-prises a stop arrangement for preventing further insertion of the intervention string assembly into the SDLM. Also, the SDLM comprises means for locking parts of the inter-vention string assembly in place during certain operation-al stages.
In one embodiment of the invention, the SDLM comprises ac-cess for a kill line to be attached, should there occur a need to kill the well. In one embodiment of the invention, the kill line is run and operated from the vessel used for the subsea intervention operation.
In one embodiment of the invention, the whole or parts of the SDLM is incorporated as a part of a permanent subsea wellhead system. Typically, the valve assemblies could form part of such a permanent system.
The SDIM is a device that, together with the intervention tools themselves, forms an intervention string assembly of the subsea deployment system.
The SDIM comprises a tubular element, hereinafter denoted as "flush pipe" and inner seal/latch subs to be mounted on the intervention tool string of interest. In one embodi-ment of the intervention, the tool string is mounted in-side the flush pipe with at least one seal/latch sub pro-vided in each endportion of the intervention tool string.
In a preferred embodiment of the invention, the outer sur-face of the flush pipe is uniform and smooth and forms a seal against the SDLM's seal arrangement. Hence, when the SDIM is stung into the dynamic seal of the SDLM, this forms a seal in the annular space between the well and the open environment. Preferably, another seal of similar pur-pose is provided on the inside of the flush pipe present in the annular space defined by the flush pipe and the seal/latch subs attached to the tool string.
In one embodiment of the invention, in the bottom of the tool string, there is a connector sub for connecting the tool string to the anti-blowout sub of the SDLM. In one embodiment of the invention, the connector mechanism com-prises a standard latch system, such as a GS type latch.
In another embodiment of the invention, the anti-blowout sub latches onto the flush pipe of the SDIM (and not the tool string). In this embodiment, the anti-blowout sub is hollow and allows the intervention tool string to be run through it.
In a preferred embodiment of the invention, at least one of the seal/latch subs comprises a latch that attaches the intervention string to the flush pipe.
In one embodiment of the invention, the flush pipe does not cover parts of the tool string during installation.
Typically, this involves cases where the tool string can be made of similar uniform shape and outer diameter as the flush pipe, and/or cases where said non-covered parts of the tool string are going to be permanently left in the well, such as for zone isolation devices. In one embodi-ment of the invention, the flush pipe is omitted. This would typically apply for cases where the entire tool string can be made of similar uniform shape and outer di-ameter as the flush pipe.
In a preferred embodiment of the invention, the valve as-sembly includes a double set of flapper type valves, where the upper is a tri-arm flapper and the lower is a con-ventional flapper valve. In one embodiment of the invent-ion, the upper tri-arm flapper valve opens by means of forcing the intervention string assembly into it whereupon the lower flapper automatically opens as the two valves are mechanically hinged. Hence, the lower valve may be able to contain elastomer seals, sealing surfaces and other features that should not be exposed to mechanical contact with the intervention string. In summary, for this embodiment, the upper tri-arm flapper is to be considered a mechanical activation mechanism for the lower flapper that is the real barrier/sealing mechanism towards the wellbore. In one embodiment of the invention, the valve/
valve assembly is spring-loaded and biases towards a closed position. In this case, should the intervention string be retrieved out of the valve assembly, the valves will automatically close.
In one embodiment of the invention, the above described valves are complemented with another valve, typically a ball- or a gate valve, located below the other valves.
This valve enables pressure testing of seal integrity at the time of stinging the tool string assembly into the SDLM. In another embodiment of the invention, this latter valve fully replaces the need for one or both of the de-scribed flapper valves and is the only valve that is re-quired for the described purposes.
In other embodiments of the invention, the valve assembly includes or comprises alternative valve types, such as ball valves, gate valves and other valves as well as a combination of such type valves. These valves could be op-erated mechanically, electrically, hydraulically or by means of other relevant forces, using intervention tools or surface operated electrical, hydraulic or other surface operation mechanisms connected to the subsea mounted equipment. Also, wireless activation signals could be ap-plied to activate the valves.
In one embodiment of the invention, the SDLM comprises an anti-blowout system. In one embodiment of the invention, this is a device that is pre-installed and is centered in the bore of the SDLM, an anti-blowout sub, which attaches to the intervention string assembly during deployment. The anti-blowout sub has an OD that is larger than the ID of the SDLM above the hang-off point of the anti-blowout sub.
Hence, the intervention string can not be blown out of the well.
In one embodiment of the invention, the anti-blowout sub and the matching anti-blowout profile in the SDLM have the shape and characteristics of a dampener. In one embodiment of the invention, the two components form the male and fe-male of a hydraulic dampener, where fluid becomes trapped between the anti-blowout sub and the anti-blowout profile of the SDLM, and the said fluid only can escape via narrow channels that reduce in size or number the more fluid that is displaced. Hence, a gradual dampening pattern is achieved in order to avoid system damage due to hard im-pacts between the anti-blow-out sub and the SDLM. In other embodiments of the invention, the dampener mechanism is based on other known dampener principles such as springs, friction dampeners and other.
In another embodiment of the invention, the anti-blowout function is handled by means of a gripping/locking system that prevents upward movement of the intervention string assembly. In one embodiment of the invention, upward move-ment of the intervention string assembly directly mechani-cally activates the gripping/locking system. In another embodiment of the invention, the gripping/locking system is activated by means of sensors detecting unwanted situ-ations (leakage, kick, blowout, unexpected upward movement of the intervention string assembly). Such sensors could include detection devices for motion, position, pressure, fluid flowrate, fluid composition, volumetric changes and other. In one embodiment of the invention, the grip-ping/locking system is operator activated. In another em-bodiment of the invention, the gripping/locking system comprises a combination of some or all of the herein men-tioned activation features.
In one embodiment of the invention, the gripping/locking system includes slips that slide gently along the inter-vention string assembly while this is being deployed into the well, but makes a firm grip at the instant this starts to move upwards. For deploying out of the well, the slips are foreseen retrieved/removed radial to some distance away from the intervention string assembly in order to de-ploy this out of the well (i.e. upward movement), but linked, in a fail-safe mode, to a release mechanism that activate the slips and make them grip the intervention string assembly in case an un-wanted event (e.g. a blow-out, a kick or similar) should take place. Such an un-wanted event could be indicated by means of monitoring the speed of the upward movement of the intervention string assembly, the fluid displacement into the well during de-ployment out, acceleration or other indicators of unwanted events, or a combination of such.
In one embodiment of the invention, the gripping/locking feature is ensured by means of operator activation of the annular bag that in one embodiment forms part of the seal arrangement of the SDLM. Here, the annular bag is not fully inflated against the intervention string assembly during normal operations, but only so in the case of an emergency.
In a preferred embodiment of the invention, the SDLM com-prises flushing systems in order to remove unwanted fluids from contained spaces before opening access to the well, to the open environment, to flowlines or similar. zn one embodiment of the invention, flushing lines are run and operated from the vessel used for the subsea intervention operation. In another embodiment of the invention, dedi-cated vessels/tanks and pump systems are used for flushing purposes.
In one embodiment of the invention, the SDLM and acces-sories comprises design and system to avoid fluids being trapped in contained spaces, which can prevent system functionality.
In a preferred embodiment of the invention, the SDLM and accessories comprises means for pressure testing and moni-toring of such during all relevant operational stages.
In a preferred embodiment of the invention, the SDLM and accessories comprises means for monitoring of operational parameters such as pressure, temperature, fluid flow rate, volume displacement and fluid properties during all stages of the operation. In a preferred embodiment of the inven-tion, the SDLM comprise a position indicator system that corresponds with the intervention string assembly.
In a preferred embodiment of the invention, the SDLM com-prises a stop arrangement for preventing further insertion of the intervention string assembly into the SDLM. Also, the SDLM comprises means for locking parts of the inter-vention string assembly in place during certain operation-al stages.
In one embodiment of the invention, the SDLM comprises ac-cess for a kill line to be attached, should there occur a need to kill the well. In one embodiment of the invention, the kill line is run and operated from the vessel used for the subsea intervention operation.
In one embodiment of the invention, the whole or parts of the SDLM is incorporated as a part of a permanent subsea wellhead system. Typically, the valve assemblies could form part of such a permanent system.
The SDIM is a device that, together with the intervention tools themselves, forms an intervention string assembly of the subsea deployment system.
The SDIM comprises a tubular element, hereinafter denoted as "flush pipe" and inner seal/latch subs to be mounted on the intervention tool string of interest. In one embodi-ment of the intervention, the tool string is mounted in-side the flush pipe with at least one seal/latch sub pro-vided in each endportion of the intervention tool string.
In a preferred embodiment of the invention, the outer sur-face of the flush pipe is uniform and smooth and forms a seal against the SDLM's seal arrangement. Hence, when the SDIM is stung into the dynamic seal of the SDLM, this forms a seal in the annular space between the well and the open environment. Preferably, another seal of similar pur-pose is provided on the inside of the flush pipe present in the annular space defined by the flush pipe and the seal/latch subs attached to the tool string.
In one embodiment of the invention, in the bottom of the tool string, there is a connector sub for connecting the tool string to the anti-blowout sub of the SDLM. In one embodiment of the invention, the connector mechanism com-prises a standard latch system, such as a GS type latch.
In another embodiment of the invention, the anti-blowout sub latches onto the flush pipe of the SDIM (and not the tool string). In this embodiment, the anti-blowout sub is hollow and allows the intervention tool string to be run through it.
In a preferred embodiment of the invention, at least one of the seal/latch subs comprises a latch that attaches the intervention string to the flush pipe.
In one embodiment of the invention, the flush pipe does not cover parts of the tool string during installation.
Typically, this involves cases where the tool string can be made of similar uniform shape and outer diameter as the flush pipe, and/or cases where said non-covered parts of the tool string are going to be permanently left in the well, such as for zone isolation devices. In one embodi-ment of the invention, the flush pipe is omitted. This would typically apply for cases where the entire tool string can be made of similar uniform shape and outer di-ameter as the flush pipe.
In a preferred embodiment of the invention, the flush pipe includes a so-called "no-go profile" in the top portion that matches a similar profile in the SDLM. This feature physically prevents the flush tube from being deployed lower than the no-go profile permits. One intention with the no-go feature is to ease exact depth determination.
Also, the no-go feature is a very important system feature in case of an emergency. Should there occur a need to drop the SDIM, this will stop in a controlled manner in the no-go profile. Otherwise, a falling SDIM could drop through the downhole safety valve and create a severe situation.
In one embodiment of the invention, the no-go system in-cludes one or more dampening functions to enable a smooth landing of the SDIM into the SDLM, said functions could be hydraulic-, spring-, friction-based or other damper prin-ciples.
In some situations, for example in the case of tool strings of varying outer diameter and shape, like pro-duction logging strings, it might not be feasible to use solid, large size seal/latch subs. In particular, such seal/latch subs could conflict with the operational scope if placed in the bottom of such tool strings. In one em-bodiment of the invention, hollow, fluted, expandable or similar feature seal/latch subs are used. In another em-bodiment of the invention, instead of a seal/latch sub, the bottom and/or other parts of the flush pipe is provid-ed with a valve system. This could comprise one or more ball valves, gate valves, flapper valves, or other types and/or combination of valves. The operation of the valve system could be by means of a shifting tool located in the bottom of the tool string, or by means of surface operator controls that are mechanical, hydraulic, electrical, fi-bre-optical and/or wireless activation based. Remote acti-vation techniques, such as wireless signals based on acoustic, electromagnetic, pressure pulse or other methods known per se, could be applied to activate the valve sys-tem.
In one embodiment of the invention, the SDIM comprises a system for fluid displacement. Typically, in order to avoid pollution when deploying out of the hole, this fea-ture could be applied in cases where it is not possible to obtain a good seal between the flush pipe and the seal/
latch subs after the tool string has been in the well.
In a preferred embodiment of the invention, the SDIM com-prises passive modules of a position indicator system.
This could be magnets, weak radioactive sources and other types of passive system components known per se. In anot-her embodiment of the invention, the SDIM comprises active position indicator modules.
In the event of loosing the tool string in the well and the flush pipe needs to be withdrawn from the hole "on its own", a plug would normally be run in the bottom of the flush pipe. In a preferred embodiment of the invention, the bottom section of the flush pipe is compatible.with plugs, by means of having necessary reinforcements and/or plug setting profiles.
In most relevant subsea well intervention cases, the sub-sea well of interest will produce into a manifold that re-ceives flow from a number of wells. Hence, the manifold will be pressurised during the entire subsea intervention operation. This prohibits displaced fluids from the de-ployment operation to be routed into the manifold. Also, in most cases, the downhole safety valve (typically a flapper valve) will be closed and have a significant pres-sure under it, hence displaced fluids can not be routed into the well neither. To avoid fluids being*trapped, hence preventing the subsea deployment operation from be-coming feasible, a volume monitoring and storage module (VMSM) is introduced.
In a preferred embodiment of the invention, the VMSM com-prises components for monitoring in- and out-flux of flu-ids from the well as well as other relevant data when de-ploying in and out of the well. In one embodiment of the invention, the instrumentation of the VMSM includes sen-sors for measuring pressure, temperature, flow rate, fluid composition, volumetric changes, density and other rele-vant parameters in order to gain sufficient control of what fluids goes in and out of the well during the various operational steps.
In one embodiment of the invention, the VMSM also com-prises a system for handling and/or storing fluids that are displaced and replaced during the operational sequen-ces. In one embodiment of the invention, the VMSM com-prises a tank, located at the seabed or at the vessel it-self, that fluids are routed to while deploying into the well and returned from when deploying out of the well.
In another embodiment of the invention, rather than using a tank, available lines that are permanently connected to the well of interest, are used for displacement and re-placement of fluids. In one embodiment of the invention, such line could be a so-called "annulus line".
In one embodiment of the invention, the VMSM comprises a pump system that enables displacement of fluids to the production header while deploying in, and retrieval of fluids, from the same header or an alternative location, when deploying out of the well.
In one embodiment of the invention, a line from a dedi-cated tank at the seabed or the surface vessel supplies a hydrate inhibitor that is routed into the wellbore when deploying out of the well. In that way, excessive handling of wellbore fluids is avoided.
In one embodiment of the invention, access to the wellbore fluid is achieved by mounting the VMSM onto the choke bridge of a subsea wellhead. In another embodiment of the invention, the same access is achieved by means of dedi-cated ports in the SDLM or an alternative location on the subsea stack and/or flowline system.
The subsea deployment system according to the present in-vention will typically be applied for all subsea well in-tervention operations. In general, by means of eliminating or at least reducing the riser of a standard subsea inter-vention stack as well as providing a mean for intervening very long tool strings in one operational step, the subsea deployment system could be a valuable system component in each and every subsea intervention operation.
The subsea deployment system enables operations, that oth-erwise would require several runs in the hole, to be per-formed in only one run. Typically, such operations involve deploying long perforation guns, zonal isolation strings or data logging strings.
In the case of a horizontal x-mas tree, a typical subsea deployment and intervention method according to the in-vention would include the following steps:
= Pull the debris cap off the tree.
= Mount the SDLM on top of the wellhead or equivalent, using an appropriate connector sub.
= Mount the BOP on top of the subsea lubricator module.
= Pull the tree plugs of the horizontal x-mas tree. A
small riser section on top of the SDLM and BOP might be required to get sufficient space. Upon pulling the tree plugs, the DHSV and the SDLM valve assembly forms the remaining barriers.
= Mount the tool string inside the flush pipe, assem-bling component by component, whilst the lower seg-ments are lowered into the sea. Inside the flush pipe, seal/latch joints are attached to the top and bottom of the tool string in order to form seals be-tween the inside of the flush pipe and the outer en-vironment. Typically, the assembly operation is con-ducted some horizontal distance away from the well-head in case of accidentally dropped objects.
= Prior to building the cable head and mounting this on top of the tool string, the cable is tread through the grease injection head.
= When the SDIM is assembled: The vessel is positioned above the well and the SDIM lowered into the sea with the grease injection head following closely behind (above), both held by their respective wires and guiding systems.
= The bottom of the SDIM/flush pipe is guided into the BOP and the SDLM. Now, the SDIM forms a seal against the SDLM dynamic seal, whereupon it latches onto the anti-blowout sub.
= A pressure test is conducted to confirm seal inte-grity across the dynamic seal of the SDLM. For hori-zontal x-mas trees, this pressure test is conducted against a valve in the SDLM valve assembly. For ver-tical x-mas trees, this pressure test could be con-ducted against one of the valves in the tree itself.
= Sea water that is trapped between the bottom of the SDIM and the SDLM valve assembly is removed by means of the SDLM flushing systems. This is done to avoid hydrate and similar problems that might occur when sea water becomes mixed with well fluids.
= The anti-blowout sub is released from the SDLM and the SDIM is continued lowered into the hole.
= The SDLM valve assembly is opened and the SDIM is lowered further, until the top of the SDIM is inside the SDLM and the no-go profiles meet.
= The SDIM is anchored to the SDLM top section.
= The grease injection head is lowered on top of and attached to the BOP. Now, the total "lubricator" is in place.
= Sea water that is trapped between the top of the SDIM
and the grease injection head is removed by means of the SDLM flushing systems.
= The tool string is released from the flush pipe. This can be achieved by means of applying forces to the wireline cable or coil tubing, or by means of apply-ing hydraulic, electrical, mechanical or other forces and/or impulses to the flush pipe through the wire-line, coil tubing or directly from the vessel to the SDLM itself. Also, wireless communication methods could be applied for this purpose.
= The tool string is run to the well section of inter-est, whereupon it performs the relevant operation, before it is retrieved out of the well.
= The tool string is pulled into the flush pipe and latches onto the flush pipe's seal/latch sub pro-files. The seals in the seal/latch subs in the top and bottom of the tool string ensures that pollutants from the well that might have attached to the tool string are now contained inside the flush pipe while deploying this out of the well and through open wa-ter.
= Prior to disconnecting the grease injection head (GIH) and pulling the flush pipe with the tool string out of the BOP, the volume between the grease injec-tion head and the flush pipe is flushed with a fluid that replaces all well fluids and other contaminants.
Typically, the replacement fluid is characterised by being harmless to the environment as well as being of a hydrate preventive nature.
= In one embodiment of the invention, the flush pipe and the SDIM are flushed with a fluid that replaces most of the well fluids in order to avoid excessive exposure of such on the vessel.
= The grease injection head (GIH) is loosened from the BOP and lifted slightly above the rest of the lubri-cator stack.
= The SDIM is loosened from the SDLM and retrieved out of the well. The grease injection head (GIH) is re-trieved in the same operation.
= Upon having passed the SDLM valve housing the anti-blowout sub connected to the SDZM lands in the anti-blowout profile of the SDLM.
= The SDLM valve assembly is closed.
Also, the no-go feature is a very important system feature in case of an emergency. Should there occur a need to drop the SDIM, this will stop in a controlled manner in the no-go profile. Otherwise, a falling SDIM could drop through the downhole safety valve and create a severe situation.
In one embodiment of the invention, the no-go system in-cludes one or more dampening functions to enable a smooth landing of the SDIM into the SDLM, said functions could be hydraulic-, spring-, friction-based or other damper prin-ciples.
In some situations, for example in the case of tool strings of varying outer diameter and shape, like pro-duction logging strings, it might not be feasible to use solid, large size seal/latch subs. In particular, such seal/latch subs could conflict with the operational scope if placed in the bottom of such tool strings. In one em-bodiment of the invention, hollow, fluted, expandable or similar feature seal/latch subs are used. In another em-bodiment of the invention, instead of a seal/latch sub, the bottom and/or other parts of the flush pipe is provid-ed with a valve system. This could comprise one or more ball valves, gate valves, flapper valves, or other types and/or combination of valves. The operation of the valve system could be by means of a shifting tool located in the bottom of the tool string, or by means of surface operator controls that are mechanical, hydraulic, electrical, fi-bre-optical and/or wireless activation based. Remote acti-vation techniques, such as wireless signals based on acoustic, electromagnetic, pressure pulse or other methods known per se, could be applied to activate the valve sys-tem.
In one embodiment of the invention, the SDIM comprises a system for fluid displacement. Typically, in order to avoid pollution when deploying out of the hole, this fea-ture could be applied in cases where it is not possible to obtain a good seal between the flush pipe and the seal/
latch subs after the tool string has been in the well.
In a preferred embodiment of the invention, the SDIM com-prises passive modules of a position indicator system.
This could be magnets, weak radioactive sources and other types of passive system components known per se. In anot-her embodiment of the invention, the SDIM comprises active position indicator modules.
In the event of loosing the tool string in the well and the flush pipe needs to be withdrawn from the hole "on its own", a plug would normally be run in the bottom of the flush pipe. In a preferred embodiment of the invention, the bottom section of the flush pipe is compatible.with plugs, by means of having necessary reinforcements and/or plug setting profiles.
In most relevant subsea well intervention cases, the sub-sea well of interest will produce into a manifold that re-ceives flow from a number of wells. Hence, the manifold will be pressurised during the entire subsea intervention operation. This prohibits displaced fluids from the de-ployment operation to be routed into the manifold. Also, in most cases, the downhole safety valve (typically a flapper valve) will be closed and have a significant pres-sure under it, hence displaced fluids can not be routed into the well neither. To avoid fluids being*trapped, hence preventing the subsea deployment operation from be-coming feasible, a volume monitoring and storage module (VMSM) is introduced.
In a preferred embodiment of the invention, the VMSM com-prises components for monitoring in- and out-flux of flu-ids from the well as well as other relevant data when de-ploying in and out of the well. In one embodiment of the invention, the instrumentation of the VMSM includes sen-sors for measuring pressure, temperature, flow rate, fluid composition, volumetric changes, density and other rele-vant parameters in order to gain sufficient control of what fluids goes in and out of the well during the various operational steps.
In one embodiment of the invention, the VMSM also com-prises a system for handling and/or storing fluids that are displaced and replaced during the operational sequen-ces. In one embodiment of the invention, the VMSM com-prises a tank, located at the seabed or at the vessel it-self, that fluids are routed to while deploying into the well and returned from when deploying out of the well.
In another embodiment of the invention, rather than using a tank, available lines that are permanently connected to the well of interest, are used for displacement and re-placement of fluids. In one embodiment of the invention, such line could be a so-called "annulus line".
In one embodiment of the invention, the VMSM comprises a pump system that enables displacement of fluids to the production header while deploying in, and retrieval of fluids, from the same header or an alternative location, when deploying out of the well.
In one embodiment of the invention, a line from a dedi-cated tank at the seabed or the surface vessel supplies a hydrate inhibitor that is routed into the wellbore when deploying out of the well. In that way, excessive handling of wellbore fluids is avoided.
In one embodiment of the invention, access to the wellbore fluid is achieved by mounting the VMSM onto the choke bridge of a subsea wellhead. In another embodiment of the invention, the same access is achieved by means of dedi-cated ports in the SDLM or an alternative location on the subsea stack and/or flowline system.
The subsea deployment system according to the present in-vention will typically be applied for all subsea well in-tervention operations. In general, by means of eliminating or at least reducing the riser of a standard subsea inter-vention stack as well as providing a mean for intervening very long tool strings in one operational step, the subsea deployment system could be a valuable system component in each and every subsea intervention operation.
The subsea deployment system enables operations, that oth-erwise would require several runs in the hole, to be per-formed in only one run. Typically, such operations involve deploying long perforation guns, zonal isolation strings or data logging strings.
In the case of a horizontal x-mas tree, a typical subsea deployment and intervention method according to the in-vention would include the following steps:
= Pull the debris cap off the tree.
= Mount the SDLM on top of the wellhead or equivalent, using an appropriate connector sub.
= Mount the BOP on top of the subsea lubricator module.
= Pull the tree plugs of the horizontal x-mas tree. A
small riser section on top of the SDLM and BOP might be required to get sufficient space. Upon pulling the tree plugs, the DHSV and the SDLM valve assembly forms the remaining barriers.
= Mount the tool string inside the flush pipe, assem-bling component by component, whilst the lower seg-ments are lowered into the sea. Inside the flush pipe, seal/latch joints are attached to the top and bottom of the tool string in order to form seals be-tween the inside of the flush pipe and the outer en-vironment. Typically, the assembly operation is con-ducted some horizontal distance away from the well-head in case of accidentally dropped objects.
= Prior to building the cable head and mounting this on top of the tool string, the cable is tread through the grease injection head.
= When the SDIM is assembled: The vessel is positioned above the well and the SDIM lowered into the sea with the grease injection head following closely behind (above), both held by their respective wires and guiding systems.
= The bottom of the SDIM/flush pipe is guided into the BOP and the SDLM. Now, the SDIM forms a seal against the SDLM dynamic seal, whereupon it latches onto the anti-blowout sub.
= A pressure test is conducted to confirm seal inte-grity across the dynamic seal of the SDLM. For hori-zontal x-mas trees, this pressure test is conducted against a valve in the SDLM valve assembly. For ver-tical x-mas trees, this pressure test could be con-ducted against one of the valves in the tree itself.
= Sea water that is trapped between the bottom of the SDIM and the SDLM valve assembly is removed by means of the SDLM flushing systems. This is done to avoid hydrate and similar problems that might occur when sea water becomes mixed with well fluids.
= The anti-blowout sub is released from the SDLM and the SDIM is continued lowered into the hole.
= The SDLM valve assembly is opened and the SDIM is lowered further, until the top of the SDIM is inside the SDLM and the no-go profiles meet.
= The SDIM is anchored to the SDLM top section.
= The grease injection head is lowered on top of and attached to the BOP. Now, the total "lubricator" is in place.
= Sea water that is trapped between the top of the SDIM
and the grease injection head is removed by means of the SDLM flushing systems.
= The tool string is released from the flush pipe. This can be achieved by means of applying forces to the wireline cable or coil tubing, or by means of apply-ing hydraulic, electrical, mechanical or other forces and/or impulses to the flush pipe through the wire-line, coil tubing or directly from the vessel to the SDLM itself. Also, wireless communication methods could be applied for this purpose.
= The tool string is run to the well section of inter-est, whereupon it performs the relevant operation, before it is retrieved out of the well.
= The tool string is pulled into the flush pipe and latches onto the flush pipe's seal/latch sub pro-files. The seals in the seal/latch subs in the top and bottom of the tool string ensures that pollutants from the well that might have attached to the tool string are now contained inside the flush pipe while deploying this out of the well and through open wa-ter.
= Prior to disconnecting the grease injection head (GIH) and pulling the flush pipe with the tool string out of the BOP, the volume between the grease injec-tion head and the flush pipe is flushed with a fluid that replaces all well fluids and other contaminants.
Typically, the replacement fluid is characterised by being harmless to the environment as well as being of a hydrate preventive nature.
= In one embodiment of the invention, the flush pipe and the SDIM are flushed with a fluid that replaces most of the well fluids in order to avoid excessive exposure of such on the vessel.
= The grease injection head (GIH) is loosened from the BOP and lifted slightly above the rest of the lubri-cator stack.
= The SDIM is loosened from the SDLM and retrieved out of the well. The grease injection head (GIH) is re-trieved in the same operation.
= Upon having passed the SDLM valve housing the anti-blowout sub connected to the SDZM lands in the anti-blowout profile of the SDLM.
= The SDLM valve assembly is closed.
= The volume between the SDLM valve assembly and the bottom of the SDIM is flushed with a fluid that re-places all well fluids and other contaminants.
= The SDIM is released from the anti-blowout sub. This can be achieved by means of applying forces to the wireline cable or coil tubing, or by means of apply-ing hydraulic, electrical, mechanical or other forces and/or impulses to the flush pipe through the wire-line, coil tubing or directly from the vessel to the SDLM itself. Also, wireless communication methods could be applied for this purpose.
= The SDIM is pulled out of the lubricator stack, whereupon the SDIM and the grease injection head are retrieved to the intervention vessel and disassemb-led.
= The x-mas tree plugs are reinstalled and pressure tested.
= Thereupon the BOP module and the subsea deployment lubricator module are retrieved.
= The debris cap is reinstalled and the operation is finished.
In what follows is described a non-limiting exemplary embodi-ment of a preferred embodiment which is visualized in the following drawings, in which:
Figure 1 shows a simplified illustration of the overall lubricator system according to the present invention as it appears when rigged up at the seabed, with an intervention operation in progress.
Figure 2 shows in a larger scale and partly in cross sec-tion the Subsea Deployment Lubricator Module (SDLM) with schematically illustrated internal features.
Figure 3 shows in smaller scale a view of the Subsea De-ployment Intervention Module (SDIM).
= The SDIM is released from the anti-blowout sub. This can be achieved by means of applying forces to the wireline cable or coil tubing, or by means of apply-ing hydraulic, electrical, mechanical or other forces and/or impulses to the flush pipe through the wire-line, coil tubing or directly from the vessel to the SDLM itself. Also, wireless communication methods could be applied for this purpose.
= The SDIM is pulled out of the lubricator stack, whereupon the SDIM and the grease injection head are retrieved to the intervention vessel and disassemb-led.
= The x-mas tree plugs are reinstalled and pressure tested.
= Thereupon the BOP module and the subsea deployment lubricator module are retrieved.
= The debris cap is reinstalled and the operation is finished.
In what follows is described a non-limiting exemplary embodi-ment of a preferred embodiment which is visualized in the following drawings, in which:
Figure 1 shows a simplified illustration of the overall lubricator system according to the present invention as it appears when rigged up at the seabed, with an intervention operation in progress.
Figure 2 shows in a larger scale and partly in cross sec-tion the Subsea Deployment Lubricator Module (SDLM) with schematically illustrated internal features.
Figure 3 shows in smaller scale a view of the Subsea De-ployment Intervention Module (SDIM).
Figure 4 shows partly in cross section a view of the SDIM
in figure 3 with a wireline tool string (perforation gun) mounted inside.
Figure 5 shows partly in cross section and in smaller scale a view of the SDLM and SDIM in a lst step in the process of deploying in a wireline tool string.
Figure 6 shows partly in cross section a view of the SDLM
and SDIM in a 2nd step in the process of deploying in a wireline tool string.
Figure 7 shows partly in cross section a view of the SDLM
and SDIM in a 3rd step in the process of deploying in a wireline tool string.
Figure 8 shows partly in cross section a view of the SDLM
and SDIM in a 4th step in the process of deploying in a wireline tool string Figure 9 shows partly in cross section a view of the SDLM
and SDIM in a 5th step in the process of deploying in a wireline tool string.
Figure 1 illustrates the system overview as it appears at the seabed with a wireline intervention in progress. The Subsea Deployment Module (SDLM) 101 is attached to the X-mas tree or wellhead 102. Alternatively there could be a separate module, for example a wellhead connector, between the SDLM 101 and the X-mas tree/wellhead 102, but that is not illustrated here. A BOP (Blow Out Preventer) 103 is provided on top of the SDLM 101. A Grease Injection Head (GIH) 104 is provided on top of the BOP 103. A wireline cable 105 enters the GIH 104 in a top portion of the GIH
104. Inside the illustrated subsea stack, the intervention string assembly is located. However, this is not shown in Figure 1. The Volume Monitoring and Storage Module (VMSM) 107 is connected to the production flowline 108. The VMSM
comprises a volume tank 109 as well as instrumentation 110. A kill line 111 to the vessel is shown connected to the SDLM 101. Below the X-mas tree/wellhead 102, the well-bore 112, i.e. the well itself is illustrated.
Figure 2 shows in a larger scale and partly in cross sec-tion the SDLM 101. This comprises a centre bore 201, a dy-namic seal 202, a valve assembly 203 and an anti-blowout system 206. The valve assembly 203 comprises an upper, tri-arm flapper valve 204 and a lower, conventional flap-per valve 205. Also, in this illustration, the anti-blowout system 206 comprises an anti-blowout sub 207 and a SDLM anti-blowout profile 208. In order to clean the sys-tem for unwanted fluids at given operational stages, a flushing system comprising an upper flushing bore 209 and a lower flushing bore 210 are applied. For illustrative purposes the flushing system is only indicated by bores 209, 210 in the SDLM 101. However, a person skilled in the art will be familiar with such a flushing system. The SDLM
101 also comprises a dynamic seal activation system 212 for operating (activating/deactivating) the dynamic seal 202 also known to a person skilled in the art. In the up-per portion of the SDLM 101, there is a SDIM latch 211 ar-ranged for attaching to the intervention string assembly.
Also, a lip or "no-go profile" 213 extending from the sur-face in the top portion of the bore 201 of the SDLM 101 is provided for receiving a corresponding profile of the SDIM
301, thereby preventing further deployment of the SDIM 301 in the bore 201 of the SDLM 101. The kill line 111 to the vessel is also illustrated. Accessories such as access lines, pumps, fittings, check valves, seals and similar are not shown. However, such accessories are known to a person skilled in the art.
Figure 3 shows the SDIM 301 as it appears when assembled.
In the upper portion, this module has an outer latch pro-file 312 and the SDIM no-go profile 313 as mentioned above. In the bottom, sticking out of the SDIM 301, a GS
latch 311 is illustrated. The function, and purpose of the components herein are explained in connection with figures 5-9. A portion of a wireline cable 105 extending to the surface is also illustrated in the figures.
Figure 4 illustrates the internal system components of the SDIM 301. The flush pipe 302 forms the outer body of the SDIM 301. This is a pipe element having an outer surface finish that enable the dynamic seal 202 of Figure 2 to provide a seal against it. A wireline tool string 314 is mounted inside the flush pipe 302. Said tool string 314 comprises a cable head 303, an upper seal/latch sub 304 with its seal 305 and latch 306, the wireline tool 314 it-self, in this example a perforation gun 307, a bottom seal/latch sub 308 with a seal 309 (no latch included on this sub) and a GS Latch 311. The GS latch 311 is provided for connecting the wireline tool string 314 onto the anti-blowout sub 207 illustrated in Figure 2. In the upper end of the flush pipe 302, there is an outer latch profile 312 that allows the flush pipe 302 to be anchored to the SDLM
101 (cf. Figure 2 - the SDIM latch 211) after installation and a SDIM no-go profile 313 that matches the SDLM no-go profile 213 of Figure 2.
Figure 5 shows the lst step in the process of deploying in a well service tool string using the Subsea Deployment Module. In the figure, the SDIM 301 is being lowered into the bore 201 of the SDLM 101, whereupon the GS latch 311 attaches to the anti-blowout sub 207.
Figure 6 shows the 2a step of the operation. Upon a suc-cessful connection of the GS latch 311 onto the anti-blowout sub 207, the anti-blowout sub 207 is released from the SDLM 101. The connection and release mechanism between the anti-blowout sub 207 and the SDLM 101 is not shown.
However, such a release mechanism is known to a person skilled in the art and could for example, but not limited to, be a latch mechanism operated by applying forces on the wireline wire, or a release mechanism operated from the vessel or another remote location by means of hydrau-lic, electrical or mechanical impulses and/or activation mechanisms, or other known attachment/release mechanisms.
Further, the SDIM 301 with the anti-blowout sub 207 is lowered further until it contacts the tri-arm flapper valve 204. This also forces the conventional flapper valve 205 to open, whereupon the SDIM 301 with the anti-blowout sub 207 is further lowered towards and into the wellbore.
Figure 7 shows the 3rd step in the process. Here, the SDIM
301 with the anti-blowout sub 207 is further lowered to-wards and into the wellbore until the flush pipe 302 lands inside the SDLM 101. This takes place when the SDIM no-go profile 313 has made a physical stop in the SDLM no-go profile 213. Now, the SDIM latch 211 of the SDLM 101 is aligned with the Outer Latch Profile 312 of the flush pipe 302.
Figure 8 shows the 4th step of the operation. Here, the SDIM latch 211 of the SDLM 101 is activated to attach onto the outer latch profile 312 of the flush pipe 302, hence the flush pipe 302 becomes attached to the SDLM 101.
Figure 9 shows the 5th step in the process. Here, the wire-line tool 314 is released from the flush pipe 302 by means of releasing latch 306 of the upper seal/latch sub 304.
When the latch 306 is disconnected, the wireline tool 314 is free to be intervened into the well. Prior to releasing the latch 306, the Grease Injection Head (GIH, cf. 104 in Figure 1) is mounted on top of the SDLM 101 in order to ensure that all required barriers between the well and the outer environment are in place prior to the well interven-tion. In this example, the anti-blowout sub 207 follows the wireline tool 314 into the well during the well inter-vention. In a preferred embodiment of the invention, the anti-blowout sub 207 attaches to the flush pipe 302 di-rectly and does not follow the wireline tool 314 into the well. When deploying out of the well, the sequence de-scribed in figures 5-9 is mainly reversed, with some minor variations. Flushing to displace unwanted fluids might be required in one or more steps to avoid pollution to the sea when pulling 'the SDIM 301 out of the SDLM 101 after ended operation.
in figure 3 with a wireline tool string (perforation gun) mounted inside.
Figure 5 shows partly in cross section and in smaller scale a view of the SDLM and SDIM in a lst step in the process of deploying in a wireline tool string.
Figure 6 shows partly in cross section a view of the SDLM
and SDIM in a 2nd step in the process of deploying in a wireline tool string.
Figure 7 shows partly in cross section a view of the SDLM
and SDIM in a 3rd step in the process of deploying in a wireline tool string.
Figure 8 shows partly in cross section a view of the SDLM
and SDIM in a 4th step in the process of deploying in a wireline tool string Figure 9 shows partly in cross section a view of the SDLM
and SDIM in a 5th step in the process of deploying in a wireline tool string.
Figure 1 illustrates the system overview as it appears at the seabed with a wireline intervention in progress. The Subsea Deployment Module (SDLM) 101 is attached to the X-mas tree or wellhead 102. Alternatively there could be a separate module, for example a wellhead connector, between the SDLM 101 and the X-mas tree/wellhead 102, but that is not illustrated here. A BOP (Blow Out Preventer) 103 is provided on top of the SDLM 101. A Grease Injection Head (GIH) 104 is provided on top of the BOP 103. A wireline cable 105 enters the GIH 104 in a top portion of the GIH
104. Inside the illustrated subsea stack, the intervention string assembly is located. However, this is not shown in Figure 1. The Volume Monitoring and Storage Module (VMSM) 107 is connected to the production flowline 108. The VMSM
comprises a volume tank 109 as well as instrumentation 110. A kill line 111 to the vessel is shown connected to the SDLM 101. Below the X-mas tree/wellhead 102, the well-bore 112, i.e. the well itself is illustrated.
Figure 2 shows in a larger scale and partly in cross sec-tion the SDLM 101. This comprises a centre bore 201, a dy-namic seal 202, a valve assembly 203 and an anti-blowout system 206. The valve assembly 203 comprises an upper, tri-arm flapper valve 204 and a lower, conventional flap-per valve 205. Also, in this illustration, the anti-blowout system 206 comprises an anti-blowout sub 207 and a SDLM anti-blowout profile 208. In order to clean the sys-tem for unwanted fluids at given operational stages, a flushing system comprising an upper flushing bore 209 and a lower flushing bore 210 are applied. For illustrative purposes the flushing system is only indicated by bores 209, 210 in the SDLM 101. However, a person skilled in the art will be familiar with such a flushing system. The SDLM
101 also comprises a dynamic seal activation system 212 for operating (activating/deactivating) the dynamic seal 202 also known to a person skilled in the art. In the up-per portion of the SDLM 101, there is a SDIM latch 211 ar-ranged for attaching to the intervention string assembly.
Also, a lip or "no-go profile" 213 extending from the sur-face in the top portion of the bore 201 of the SDLM 101 is provided for receiving a corresponding profile of the SDIM
301, thereby preventing further deployment of the SDIM 301 in the bore 201 of the SDLM 101. The kill line 111 to the vessel is also illustrated. Accessories such as access lines, pumps, fittings, check valves, seals and similar are not shown. However, such accessories are known to a person skilled in the art.
Figure 3 shows the SDIM 301 as it appears when assembled.
In the upper portion, this module has an outer latch pro-file 312 and the SDIM no-go profile 313 as mentioned above. In the bottom, sticking out of the SDIM 301, a GS
latch 311 is illustrated. The function, and purpose of the components herein are explained in connection with figures 5-9. A portion of a wireline cable 105 extending to the surface is also illustrated in the figures.
Figure 4 illustrates the internal system components of the SDIM 301. The flush pipe 302 forms the outer body of the SDIM 301. This is a pipe element having an outer surface finish that enable the dynamic seal 202 of Figure 2 to provide a seal against it. A wireline tool string 314 is mounted inside the flush pipe 302. Said tool string 314 comprises a cable head 303, an upper seal/latch sub 304 with its seal 305 and latch 306, the wireline tool 314 it-self, in this example a perforation gun 307, a bottom seal/latch sub 308 with a seal 309 (no latch included on this sub) and a GS Latch 311. The GS latch 311 is provided for connecting the wireline tool string 314 onto the anti-blowout sub 207 illustrated in Figure 2. In the upper end of the flush pipe 302, there is an outer latch profile 312 that allows the flush pipe 302 to be anchored to the SDLM
101 (cf. Figure 2 - the SDIM latch 211) after installation and a SDIM no-go profile 313 that matches the SDLM no-go profile 213 of Figure 2.
Figure 5 shows the lst step in the process of deploying in a well service tool string using the Subsea Deployment Module. In the figure, the SDIM 301 is being lowered into the bore 201 of the SDLM 101, whereupon the GS latch 311 attaches to the anti-blowout sub 207.
Figure 6 shows the 2a step of the operation. Upon a suc-cessful connection of the GS latch 311 onto the anti-blowout sub 207, the anti-blowout sub 207 is released from the SDLM 101. The connection and release mechanism between the anti-blowout sub 207 and the SDLM 101 is not shown.
However, such a release mechanism is known to a person skilled in the art and could for example, but not limited to, be a latch mechanism operated by applying forces on the wireline wire, or a release mechanism operated from the vessel or another remote location by means of hydrau-lic, electrical or mechanical impulses and/or activation mechanisms, or other known attachment/release mechanisms.
Further, the SDIM 301 with the anti-blowout sub 207 is lowered further until it contacts the tri-arm flapper valve 204. This also forces the conventional flapper valve 205 to open, whereupon the SDIM 301 with the anti-blowout sub 207 is further lowered towards and into the wellbore.
Figure 7 shows the 3rd step in the process. Here, the SDIM
301 with the anti-blowout sub 207 is further lowered to-wards and into the wellbore until the flush pipe 302 lands inside the SDLM 101. This takes place when the SDIM no-go profile 313 has made a physical stop in the SDLM no-go profile 213. Now, the SDIM latch 211 of the SDLM 101 is aligned with the Outer Latch Profile 312 of the flush pipe 302.
Figure 8 shows the 4th step of the operation. Here, the SDIM latch 211 of the SDLM 101 is activated to attach onto the outer latch profile 312 of the flush pipe 302, hence the flush pipe 302 becomes attached to the SDLM 101.
Figure 9 shows the 5th step in the process. Here, the wire-line tool 314 is released from the flush pipe 302 by means of releasing latch 306 of the upper seal/latch sub 304.
When the latch 306 is disconnected, the wireline tool 314 is free to be intervened into the well. Prior to releasing the latch 306, the Grease Injection Head (GIH, cf. 104 in Figure 1) is mounted on top of the SDLM 101 in order to ensure that all required barriers between the well and the outer environment are in place prior to the well interven-tion. In this example, the anti-blowout sub 207 follows the wireline tool 314 into the well during the well inter-vention. In a preferred embodiment of the invention, the anti-blowout sub 207 attaches to the flush pipe 302 di-rectly and does not follow the wireline tool 314 into the well. When deploying out of the well, the sequence de-scribed in figures 5-9 is mainly reversed, with some minor variations. Flushing to displace unwanted fluids might be required in one or more steps to avoid pollution to the sea when pulling 'the SDIM 301 out of the SDLM 101 after ended operation.
Claims (15)
1. An apparatus for subsea deployment and/or intervention through a wellhead (102) of a petroleum well (112),the apparatus comprising:
- a first module (101) integrated in at least one portion of a subsea well intervention system assembly (102, 103) and/or a subsea production system assembly, the first module (101) comprising an intervention tool bore (201);
- a second module (301) comprising a tubular element (302) initially housing an intervention tool (314), characterized in that the second module (301) being arranged for sliding into releasable engagement with the intervention tool bore (201) of the first module (101), whereupon the intervention tool (314) is arranged for deployment of the intervention tool (314) into the wellbore (112), the apparatus being provided with or in fluid communication with at least one flushing system.
- a first module (101) integrated in at least one portion of a subsea well intervention system assembly (102, 103) and/or a subsea production system assembly, the first module (101) comprising an intervention tool bore (201);
- a second module (301) comprising a tubular element (302) initially housing an intervention tool (314), characterized in that the second module (301) being arranged for sliding into releasable engagement with the intervention tool bore (201) of the first module (101), whereupon the intervention tool (314) is arranged for deployment of the intervention tool (314) into the wellbore (112), the apparatus being provided with or in fluid communication with at least one flushing system.
2. The apparatus according to claim 1, character-ized in that at least one portion of the tool bore (201) is provided with at least one seal element (202) arranged for sealing an annulus defined by the tool bore (201) and the second module (301).
3. The apparatus according to claim 2, character-ized in that the at least one seal element is a dynamic seal (202).
4. The apparatus according to claim 1, character-ized in that the second module (301) is provided with a seal arrangement (305, 309) for sealing off an annular space defined by the tubular element (302) and the intervention tool (314).
5. The apparatus according to claim 1, character-ized in that a portion of the tool bore (201) of first module (101) comprises a valve assembly (203) which in a closed position provides a barrier between the well (112) and a downstream portion of said first module (101).
6. The apparatus according to claim 1, character-ized in that the second module (301) is provided with at least one latch device (306, 310) arranged for selectively disengaging the intervention tool (314) from the tubular element (302).
7. The apparatus according to claim 1, character-ized in that the first module (101) is provided with a bore (111') for connection of a kill line (111).
8. The apparatus according to any of the preceding claims, characterized in that the apparatus is provided with an anti-blowout device (206).
9 . The apparatus according to claim 8, character-ized in that the anti-blowout device (206) com-prises an anti-blowout sub (207) and an anti-blowout profile (208), said profile (208) being provided within or being an integrated part of a portion of the bore (201) of the first module (101), said profile (208) being arranged downstream of said sub (207), wherein an outside diameter of said sub is larger than the internal diameter of said profile (208).
10. The apparatus according to claim 9, character-ized in that the sub (207) is hollow and is arranged to engage with a portion of the tubular element (302).
11. The apparatus according to claim 8, character-ized in that the anti-blowout device (206) com-prises means arranged for gripping and locking the movement of the second module (301) in the first module (101).
12. The apparatus according to claim 11, charact-erized in that the anti-blowout device (206) comprises a slips module comprising slips arranged to glide along the outside of the second module (301) during deployment into the well (112) and, if the second module (301) is instantly moved in an upward direction out of the well (112), is arranged to grip around a portion of the second module (301).
13. The apparatus according to any of the preceding claims, characterized in that the first module (101) is provided with a stop arrangement (213) for engaging a substantially corresponding stop arrangement (313) in the second module (301), thereby preventing further insertion of the second module (301) beyond an ultimate insertion position of the second module (301) in the bore (201) of the first module (101).
14. A method for subsea deployment and/or intervention of a petroleum well (112) through a wellhead (102), characterized in that the method comprises the following steps:
- integrating a first module (101) that comprises an intervention tool bore (201), in at least one portion of a subsea well intervention system assembly (102, 103) and/or a subsea production system assembly;
- lowering a second module (301) comprising a tubular element (302) housing an intervention tool (314) into engagement with the tool bore (201) of the first module, at least a portion of the annulus defined between the tool bore (201) and the tubular element (302) being sealed;
- performing at least one flushing operation in order to remove unwanted fluids; and - running the intervention tool (314) into the wellbore (112).
- integrating a first module (101) that comprises an intervention tool bore (201), in at least one portion of a subsea well intervention system assembly (102, 103) and/or a subsea production system assembly;
- lowering a second module (301) comprising a tubular element (302) housing an intervention tool (314) into engagement with the tool bore (201) of the first module, at least a portion of the annulus defined between the tool bore (201) and the tubular element (302) being sealed;
- performing at least one flushing operation in order to remove unwanted fluids; and - running the intervention tool (314) into the wellbore (112).
15. A method for retrieval and/or deploying out of an intervention tool (314) through a wellhead (102) of a subsea petroleum well (112), characterized in that the method comprises the following steps:
- pulling the intervention tool (314) into a tubular element (302) of a second module (301), a portion of which being in engagement with and sealingly housed in a tool bore (201) of a first module (101);
- performing at least one flushing operation in order to remove unwanted fluids;
- disengaging the second module (301) housing the intervention tool (314), and - retrieving the second module (301) out of the first module (101) through open water and to a surface.
- pulling the intervention tool (314) into a tubular element (302) of a second module (301), a portion of which being in engagement with and sealingly housed in a tool bore (201) of a first module (101);
- performing at least one flushing operation in order to remove unwanted fluids;
- disengaging the second module (301) housing the intervention tool (314), and - retrieving the second module (301) out of the first module (101) through open water and to a surface.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| NO20051257A NO323513B1 (en) | 2005-03-11 | 2005-03-11 | Device and method for subsea deployment and / or intervention through a wellhead of a petroleum well by means of an insertion device |
| NO20051257 | 2005-03-11 | ||
| PCT/NO2006/000087 WO2006096069A1 (en) | 2005-03-11 | 2006-03-08 | An apparatus and a method for deployment of a well intervention tool string into a subsea well |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2602069A1 CA2602069A1 (en) | 2006-09-14 |
| CA2602069C true CA2602069C (en) | 2010-07-13 |
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ID=35266155
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2602069A Expired - Fee Related CA2602069C (en) | 2005-03-11 | 2006-03-08 | An apparatus and a method for deployment of a well intervention tool string into a subsea well |
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| Country | Link |
|---|---|
| US (1) | US20080277122A1 (en) |
| EP (1) | EP1856372A4 (en) |
| CA (1) | CA2602069C (en) |
| NO (1) | NO323513B1 (en) |
| WO (1) | WO2006096069A1 (en) |
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| US6321846B1 (en) * | 2000-02-24 | 2001-11-27 | Schlumberger Technology Corp. | Sealing device for use in subsea wells |
| US6484808B2 (en) * | 2000-06-09 | 2002-11-26 | Varco I/P, Inc. | Stripper/packer |
| NO312560B1 (en) * | 2000-08-21 | 2002-05-27 | Offshore & Marine As | Intervention module for a well |
| CA2365554C (en) * | 2000-12-20 | 2005-08-02 | Progressive Technology Ltd. | Straddle packer systems |
| US6609571B2 (en) * | 2001-03-28 | 2003-08-26 | Baker Hughes, Incorporated | Remote sub-sea lubricator |
| CA2388391C (en) * | 2002-05-31 | 2004-11-23 | L. Murray Dallas | Reciprocating lubricator |
| WO2004003338A1 (en) * | 2002-06-28 | 2004-01-08 | Vetco Aibel As | An assembly and a method for intervention of a subsea well |
| US7040394B2 (en) * | 2002-10-31 | 2006-05-09 | Weatherford/Lamb, Inc. | Active/passive seal rotating control head |
| US7066264B2 (en) * | 2003-01-13 | 2006-06-27 | Schlumberger Technology Corp. | Method and apparatus for treating a subterranean formation |
| AU2003904183A0 (en) * | 2003-08-08 | 2003-08-21 | Woodside Energy Limited | Method for completion or work-over of a sub-sea well using a horizontal christmas tree |
| CA2444043C (en) * | 2003-10-08 | 2007-04-24 | L. Murray Dallas | Well stimulation tool and method for inserting a backpressure plug through a mandrel of the tool |
| US7207384B2 (en) * | 2004-03-12 | 2007-04-24 | Stinger Wellhead Protection, Inc. | Wellhead and control stack pressure test plug tool |
| GB2415445B (en) * | 2004-06-22 | 2008-12-17 | Schlumberger Holdings | Logging plug with high integrity internal seal |
| US7219737B2 (en) * | 2004-09-21 | 2007-05-22 | Kelly Melvin E | Subsea wellhead arrangement for hydraulically pumping a well |
| NO323342B1 (en) * | 2005-02-15 | 2007-04-02 | Well Intervention Solutions As | Well intervention system and method in seabed-installed oil and gas wells |
| US7401651B2 (en) * | 2005-09-27 | 2008-07-22 | Smith International, Inc. | Wellbore fluid saver assembly |
-
2005
- 2005-03-11 NO NO20051257A patent/NO323513B1/en not_active IP Right Cessation
-
2006
- 2006-03-08 WO PCT/NO2006/000087 patent/WO2006096069A1/en active Application Filing
- 2006-03-08 EP EP06716762.7A patent/EP1856372A4/en not_active Withdrawn
- 2006-03-08 CA CA2602069A patent/CA2602069C/en not_active Expired - Fee Related
- 2006-03-08 US US11/908,398 patent/US20080277122A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| EP1856372A1 (en) | 2007-11-21 |
| NO20051257L (en) | 2006-09-12 |
| NO20051257D0 (en) | 2005-03-11 |
| NO323513B1 (en) | 2007-06-04 |
| EP1856372A4 (en) | 2014-03-12 |
| US20080277122A1 (en) | 2008-11-13 |
| WO2006096069A1 (en) | 2006-09-14 |
| CA2602069A1 (en) | 2006-09-14 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |
Effective date: 20150309 |
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| MKLA | Lapsed |
Effective date: 20150309 |