US20170204702A1 - Battery operated autonomous scale removal system for wells - Google Patents
Battery operated autonomous scale removal system for wells Download PDFInfo
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- US20170204702A1 US20170204702A1 US15/508,916 US201515508916A US2017204702A1 US 20170204702 A1 US20170204702 A1 US 20170204702A1 US 201515508916 A US201515508916 A US 201515508916A US 2017204702 A1 US2017204702 A1 US 2017204702A1
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- Prior art keywords
- lubricator
- well
- tool system
- intervention tool
- wellbore
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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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
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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
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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
- E21B23/06—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells for setting packers
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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
- E21B47/00—Survey of boreholes or wells
Definitions
- This disclosure relates generally to the field of a non-tethered autonomous well intervention tool system for removing scale and similar from a wellbore.
- the wellbore can be subsea, on an offshore platform or on land. More specifically, the present disclosure relates to a battery operated electrical tool for dissolving mineral build-up in a wellbore, where the tool is stored, deployed from and received in a lubricator and charging system mounted on top of a wellhead (Christmas tree).
- the wellbore intervention tool system may also perform other wellbore operations, e.g., production logging, setting and retrieval of plugs, and other intervention operations known in the art.
- the system may operate without the presence of a human operator at the well site, either remotely operated or autonomously at pre-determined times.
- FIG. 1 illustrates scale in a tube, where it can be understood that this will reduce or totally prevent flow through a tube as well as cause wellbore components to malfunction.
- FIG. 2 illustrates a wellhead with an attached wellhead (“christmas tree”) and a lubricator/valve system installed on top of the christmas tree. Within the lubricator, a wellbore intervention tool system is mounted. Scale build up is indicated within a conduit called production tubing.
- FIG. 2A shows an enlarged view of an example intervention tool system
- FIG. 3 illustrates that valves in the lower end of the lubricator system have been opened, followed by a wellbore intervention tool moving into the wellbore.
- FIG. 4 illustrates that one or both valves in the lower section of the lubricator system have been closed, so that the well can be flowed at a low rate with the intervention tool being downhole. Scale removal may be started.
- FIG. 5 illustrates that the intervention tool is transported up-hole, either by producing the well or by a built in propulsion drive.
- FIG. 6 illustrates that the intervention tool has latched into the top section of the lubricator/valve system, with both valves closed and well brought back to normal production.
- the present disclosure sets forth a possible solution to removing scale or paraffin in a well where the scale or paraffin removal is performed more frequently than may be performed using conventional wireline conveyed tools. Increased frequency of scale or paraffin deposits may prevent excessive buildup of such scale or paraffin deposits. Scale or paraffin removal at more frequent intervals may be performed by a system mounted on top of the wellhead, where a lubricator, isolated from the wellhead by valves built into the lower section of the intervention system, contains a scale or paraffin removal tool that can be deployed into the wellbore when required.
- the wellbore tool intervention system may include a scale or paraffin removal tool with required ancillary instrumentation attached, such as, for example, a battery package, a wet-mating electrical coupler, a propulsion system, etc.
- the wellbore tool intervention system may be deployed into the wellbore from a storage place within the lubricator and may be returned to the lubricator by causing fluid to flow from the formations external to the well thence into the well.
- the wellbore intervention tool system may contain a propulsion system built in that returns the wellbore tool system to the lubricator when required.
- a wellbore intervention tool system allows more frequent wellbore scale or paraffin removal operations than would be ordinarily performed using interventions from a vessel, workover rig or a drilling rig. More frequent deposit removal may result in the scale or paraffin deposits being of less extent than would occur with less frequent intervention; such more frequent deposit removal ensures improved production of hydrocarbons from the well.
- pressure equalizing between the wellbore and the lubricator may be performed, followed by opening of valves between the lubricator and the wellhead.
- This will enable the wellbore intervention tool system to drop, or drive down, into the wellbore where it reaches a restriction caused by scale or paraffin. Then the removal of such restriction will be commenced, until the restriction has been removed or until an internal power source (e.g., batteries) is exhausted.
- an internal power source e.g., batteries
- the wellbore intervention tool system may be transported up to the lubricator again by a built in “swab cup” that uses fluid flow from the wellbore to lift the wellbore intervention tool system.
- the wellbore intervention tool system When reaching the wellhead, the wellbore intervention tool system will be further pushed up into the lubricator and latch onto a holding device and/or an electrical coupler enabling battery recharging.
- valves between the lubricator and the wellhead can be closed and pressure tested, so that the well can commence fluid production again.
- FIG. 1 illustrates scale 14 in a tube 12 .
- the tube 12 may be, for example, a wellbore production tubing or “velocity string.” It will be appreciated that the scale 14 will reduce or totally prevent flow through the tube 14 .
- the scale 14 may also cause wellbore components to malfunction. Such scale needs to be removed, where various methods can be used, as for example mechanically breaking the scale, pulsed electrical energy pulverizing the scale, release of scale-dissolving chemicals, or abrasive means such as milling.
- FIG. 2 illustrates a wellhead 20 , for example a sea bottom wellhead with an attached christmas tree (e.g., valves 30 and 32 ).
- a lubricator system 22 may be affixed to the upper end of the wellhead.
- the lubricator system 22 may include isolation valves 22 A such as gate valves to selectively pressure isolate the lubricator system 22 from the wellhead 20 .
- the isolation valves 22 A may be operated by respective actuators 22 B.
- the actuators 22 B may be electrically, pneumatically or hydraulically operated, for example.
- the lubricator system 22 may include pressure equalization valves 28 that connect the interior of the lubricator system to below each of the isolation valves 22 A.
- the pressure equalization valves 28 may also be actuated electrically, hydraulically or pneumatically.
- the isolation valves 22 A and the pressure equalization valves 28 may be operated by a controller 29 .
- the controller 29 may be operated using, for example, telemetry from the water surface or electrical connection using a remotely operated vehicle (ROV).
- ROV remotely operated vehicle
- the lubricator system 22 may also include a pressure relief valve 24 to enable release of pressure from the interior of the lubricator system after the well intervention tool system 10 is retrieved into the lubricator system 22 .
- the pressure relief valve 24 may also be electrically, hydraulically or pneumatically operated and may be controlled by the controller 29 .
- the upper end of the lubricator system 22 may include a sealing cover 22 D that is retained in place on the upper end of the lubricator system 22 and is pressure sealed.
- the sealing cover 22 D may include an automatically operable latch 22 E to retain the wellbore intervention tool system 10 when it is retrieved into the lubricator system 22 .
- the latch 22 E may include electrical connections (not shown separately) for providing electrical power to the wellbore intervention tool system 10 , e.g., to recharge batteries therein (see FIG. 2A ).
- the sealing cover 22 D may have a profile for a retrieval and running tool, a receptacle 22 F for an electrical cable from an external power source as well as various sensors for monitoring pressure, etc. It may also contain a telemetry system for transmitting and receiving commands and data from a surface vessel or the like.
- the sealing cap 22 D may also be removed, so that a wellbore intervention pressure control system (with riser, etc.) can be landed on top of the lubricator system 22 , followed by the possibility of deploying and setting plugs and other equipment in the wellbore. Setting a plug within a tubing hanger or further down into the wellbore tubing 14 may enable a safe removal of the complete lubricator system 22 if such is required.
- the isolation valves 22 A valve system on the lower end of the lubricator system 22 may be used for pressure testing of the lubricator system 22 and enable the well to operate normally without subjecting the lubricator system 22 to wellbore production fluids and pressure when the wellbore intervention tool system 10 is not in use.
- FIG. 2A shows the wellbore intervention tool system 10 in more detail.
- the wellbore intervention tool system 10 hereinafter “tool” for convenience, may include a self-contained power supply 10 E such as batteries within a pressure sealed housing 11 .
- a control and power module 10 F disposed in the housing 11 may be used to operate a wellbore intervention device 10 A.
- the wellbore intervention device may be a scale removal device disposed proximate the bottom of the housing 11 .
- the scale removal device may be any type known in the art, including a chemical storage and release mechanism, motor-rotated blades or abrasive mills, electric shock (sparker) discharge devices, acoustic devices, heater(s) to remove paraffin deposits, or any other such device for removal of deposits in the tubing ( 12 in FIG. 1 ).
- the tool 10 may include combinations of any or all of the foregoing as well.
- the tool 10 may include a propulsion device 10 G, such as a fluid operated jet or a propeller to cause the tool 10 to move within the tube 14 during operations if gravity is insufficient to move the tool 10 downwardly to the depth of any obstruction, and to return the tool 10 to the lubricator system ( 22 in FIG.
- the housing 11 may include annular seals 10 D such as swab cups to enable free movement of the tool 10 downwardly, but may seal to engage the interior of the tubing ( 14 in FIG. 1 ) to enable fluid flow into the well to lift the tool into the lubricator system ( 22 in FIG. 2 ).
- the upper end of the housing 11 may include a mating latch 10 B to engage the latch ( 22 E in FIG. 2 ) in the lubricator system sealing cover ( 22 D in FIG. 2 ).
- the housing 11 may include centralizers 10 C to enable relatively free movement of the tool 10 in the tubing ( 14 in FIG. 2 ) and to keep the tool 10 centered in the tubing for proper operation of the scale removal device.
- Scale or paraffin build up may be indicated within the production tubing ( 14 in FIG. 2 ), for example, by a decrease in fluid production from the well. Thus it may be necessary to deploy the tool 10 .
- the tool 10 may be installed into the lubricator system ( 22 in FIG. 2 ) prior to installing the lubricator system ( 22 in FIG. 2 ) onto the wellhead ( 20 in FIG. 2 ) or the tool 10 may be installed into the lubricator system ( 22 in FIG. 2 ) by unlatching and removing the sealing cover ( 22 D in FIG. 2 ).
- Retrieval of the tool 10 may be performed by unlatching and retrieving the entire lubricator system with the tool 10 inside the lubricator system, or by unlatching the sealing cover ( 22 D in FIG. 2 ) and retrieving the tool 10 . It is also possible to perform tool replacement using an ROV in marine operations where the wellhead is on the water bottom.
- the wellbore intervention device 10 A may be any other type of wellbore tool, including, without limitation, a production logging instrument, a plug or packer setting tool or a video camera.
- FIG. 2 shows the tool 10 engaged with the latch 22 E and the isolation valves 22 A and pressure equalization valves 28 closed so that the well can operate normally.
- FIG. 3 illustrates that the pressure equalization valves 28 may be opened to equalize pressure in the well with the pressure in the lubricator system 22 .
- the isolation valves 22 A may then be opened and the latch 22 E may be released to enable the tool 10 to move downwardly through the well tubing 14 . Movement of the tool 10 into the wellbore may be by gravity or by a propulsion device ( 10 G in FIG. 2A ) in the tool 10 . It is also here illustrated that the tool performs scale or paraffin removal.
- FIG. 4 illustrates that one or both of the isolation valves 28 has been closed, so that well can be flowed at low rate with the tool 10 being in the wellbore.
- Scale or other deposit removal may then be started by operating the deposit removal device 10 A.
- the tool 10 When the tool 10 reaches the area of restriction caused by scale or paraffin, the tool 10 performs the removal of this restriction as explained above.
- the tool 10 will by move further down into the wellbore by gravity (or by use of the propulsion device 10 G in FIG. 2A , e.g., for highly inclined or horizontal wells)
- the tool 10 control and power module 10 F in FIG.
- the power and control module may be programmed to enable the tool 10 to stop itself, e.g., by energizing its swab cups ( 10 D in FIG. 2A ), a mechanical breaking mechanism or the propulsion device ( 10 G in FIG. 2A .
- a device preventing the tool 10 from going further into the wellbore than a selected depth may also be installed in the wellbore, for example, a narrow internal diameter packer or similar restriction.
- a device can be set up to trigger the power and control module ( 10 F in FIG. 2A ) to cause the tool 10 to return the lubricator/system 22 .
- An example of such device may be a contact switch, shown at 13 in FIG. 2A which would not be triggered by scale or other deposits, but would be triggered by contact with a packer or similar internal diameter restriction.
- FIG. 5 illustrates that the tool 10 is transported up-hole, either by producing the well at low flow rate or by the propulsion device ( 10 G in FIG. 2A ).
- the isolation valves 28 are opened to enable the tool 10 to enter the lubricator system 22 .
- FIG. 6 illustrates that the tool 10 has latched into the lubricator system 22 on the latch 22 E in the sealing cover 22 D. At such time the isolation valves 28 may be closed and the well brought back to normal production. The tool 10 is now coupled to the electrical coupler (part of latch 22 E) in the sealing cover 22 D so that the batteries ( 10 E in FIG. 2A ) can be charged. In some embodiments it may be possible to retrieve logged data and transmit new commands to the tool 10 through the electrical connector 22 F.
- pressure inside the lubricator system 22 may be released using the pressure relief valve 24 . Such may be performed prior to any required removal of the sealing cap 22 D or the lubricator system 22 from the wellhead 20 .
Abstract
Description
- This disclosure relates generally to the field of a non-tethered autonomous well intervention tool system for removing scale and similar from a wellbore. The wellbore can be subsea, on an offshore platform or on land. More specifically, the present disclosure relates to a battery operated electrical tool for dissolving mineral build-up in a wellbore, where the tool is stored, deployed from and received in a lubricator and charging system mounted on top of a wellhead (Christmas tree). The wellbore intervention tool system may also perform other wellbore operations, e.g., production logging, setting and retrieval of plugs, and other intervention operations known in the art. The system may operate without the presence of a human operator at the well site, either remotely operated or autonomously at pre-determined times.
- Buildup of scale and paraffin is a frequent problem in producing hydrocarbon wells, where such build up causes drop or total halt of production as well as malfunction of wellbore completion components, for example, downhole safety valves. To remove scale and paraffin deposits, wireline is rigged up on top of the wellbore, followed by an intervention where electrical or mechanical impact based tools are run into the wellbore to hammer loose the scale or cut the paraffin built up. This is a slow process due to the nature of the tools being used, but not least due to the time required to rig up and down the intervention valves, lubricator and so on. In addition, well production is lost due to the required well “shut in” (stopping of fluid production) during rigging operation. The process may also be expensive, where the cost of performing an intervention in a subsea well can amount to tens of millions of United States dollars, plus a significant lost income for the duration of the intervention.
- Due to the foregoing considerations, failures of wellbore components, for example, downhole safety valves, also take place as a result of intentionally infrequent scale removal, causing the production tubing, etc., to become partially or completely non-functional.
-
FIG. 1 . illustrates scale in a tube, where it can be understood that this will reduce or totally prevent flow through a tube as well as cause wellbore components to malfunction. -
FIG. 2 illustrates a wellhead with an attached wellhead (“christmas tree”) and a lubricator/valve system installed on top of the christmas tree. Within the lubricator, a wellbore intervention tool system is mounted. Scale build up is indicated within a conduit called production tubing. -
FIG. 2A shows an enlarged view of an example intervention tool system -
FIG. 3 illustrates that valves in the lower end of the lubricator system have been opened, followed by a wellbore intervention tool moving into the wellbore. -
FIG. 4 illustrates that one or both valves in the lower section of the lubricator system have been closed, so that the well can be flowed at a low rate with the intervention tool being downhole. Scale removal may be started. -
FIG. 5 illustrates that the intervention tool is transported up-hole, either by producing the well or by a built in propulsion drive. -
FIG. 6 illustrates that the intervention tool has latched into the top section of the lubricator/valve system, with both valves closed and well brought back to normal production. - Therefore the present disclosure sets forth a possible solution to removing scale or paraffin in a well where the scale or paraffin removal is performed more frequently than may be performed using conventional wireline conveyed tools. Increased frequency of scale or paraffin deposits may prevent excessive buildup of such scale or paraffin deposits. Scale or paraffin removal at more frequent intervals may be performed by a system mounted on top of the wellhead, where a lubricator, isolated from the wellhead by valves built into the lower section of the intervention system, contains a scale or paraffin removal tool that can be deployed into the wellbore when required.
- The wellbore tool intervention system may include a scale or paraffin removal tool with required ancillary instrumentation attached, such as, for example, a battery package, a wet-mating electrical coupler, a propulsion system, etc. The wellbore tool intervention system may be deployed into the wellbore from a storage place within the lubricator and may be returned to the lubricator by causing fluid to flow from the formations external to the well thence into the well. In some embodiments, the wellbore intervention tool system may contain a propulsion system built in that returns the wellbore tool system to the lubricator when required.
- Electrical, hydraulic or pneumatic operated impact (e.g. hammer, so called “broach” and similar) based scale removal tools can be coupled to the wellbore intervention tool system. A wellbore intervention tool system according to the present disclosure allows more frequent wellbore scale or paraffin removal operations than would be ordinarily performed using interventions from a vessel, workover rig or a drilling rig. More frequent deposit removal may result in the scale or paraffin deposits being of less extent than would occur with less frequent intervention; such more frequent deposit removal ensures improved production of hydrocarbons from the well.
- To perform a wellbore intervention, pressure equalizing between the wellbore and the lubricator may be performed, followed by opening of valves between the lubricator and the wellhead. This will enable the wellbore intervention tool system to drop, or drive down, into the wellbore where it reaches a restriction caused by scale or paraffin. Then the removal of such restriction will be commenced, until the restriction has been removed or until an internal power source (e.g., batteries) is exhausted. When the foregoing takes place, the wellbore intervention tool system may be transported up to the lubricator again by a built in “swab cup” that uses fluid flow from the wellbore to lift the wellbore intervention tool system. When reaching the wellhead, the wellbore intervention tool system will be further pushed up into the lubricator and latch onto a holding device and/or an electrical coupler enabling battery recharging.
- After the wellbore intervention tool system has been returned to the lubricator, the valves between the lubricator and the wellhead can be closed and pressure tested, so that the well can commence fluid production again.
- When scale or paraffin removal is required again, the above sequence may be repeated.
- For those skilled in the art of wellbore interventions, it will be understood that the method described herein may also be used for other type interventions, e.g., memory type production logging, and other intervention operations.
-
FIG. 1 . illustratesscale 14 in atube 12. Thetube 12 may be, for example, a wellbore production tubing or “velocity string.” It will be appreciated that thescale 14 will reduce or totally prevent flow through thetube 14. Thescale 14 may also cause wellbore components to malfunction. Such scale needs to be removed, where various methods can be used, as for example mechanically breaking the scale, pulsed electrical energy pulverizing the scale, release of scale-dissolving chemicals, or abrasive means such as milling. -
FIG. 2 illustrates awellhead 20, for example a sea bottom wellhead with an attached christmas tree (e.g.,valves 30 and 32). Alubricator system 22 may be affixed to the upper end of the wellhead. Thelubricator system 22 may includeisolation valves 22A such as gate valves to selectively pressure isolate thelubricator system 22 from thewellhead 20. Theisolation valves 22A may be operated byrespective actuators 22B. Theactuators 22B may be electrically, pneumatically or hydraulically operated, for example. Thelubricator system 22 may includepressure equalization valves 28 that connect the interior of the lubricator system to below each of theisolation valves 22A. Thepressure equalization valves 28 may also be actuated electrically, hydraulically or pneumatically. Theisolation valves 22A and thepressure equalization valves 28 may be operated by acontroller 29. Thecontroller 29 may be operated using, for example, telemetry from the water surface or electrical connection using a remotely operated vehicle (ROV). Thelubricator system 22 may also include apressure relief valve 24 to enable release of pressure from the interior of the lubricator system after the wellintervention tool system 10 is retrieved into thelubricator system 22. Thepressure relief valve 24 may also be electrically, hydraulically or pneumatically operated and may be controlled by thecontroller 29. - The upper end of the
lubricator system 22 may include asealing cover 22D that is retained in place on the upper end of thelubricator system 22 and is pressure sealed. Thesealing cover 22D may include an automaticallyoperable latch 22E to retain the wellboreintervention tool system 10 when it is retrieved into thelubricator system 22. Thelatch 22E may include electrical connections (not shown separately) for providing electrical power to the wellboreintervention tool system 10, e.g., to recharge batteries therein (seeFIG. 2A ). - The
sealing cover 22D may have a profile for a retrieval and running tool, areceptacle 22F for an electrical cable from an external power source as well as various sensors for monitoring pressure, etc. It may also contain a telemetry system for transmitting and receiving commands and data from a surface vessel or the like. The sealingcap 22D may also be removed, so that a wellbore intervention pressure control system (with riser, etc.) can be landed on top of thelubricator system 22, followed by the possibility of deploying and setting plugs and other equipment in the wellbore. Setting a plug within a tubing hanger or further down into thewellbore tubing 14 may enable a safe removal of thecomplete lubricator system 22 if such is required. - The
isolation valves 22A valve system on the lower end of thelubricator system 22 may be used for pressure testing of thelubricator system 22 and enable the well to operate normally without subjecting thelubricator system 22 to wellbore production fluids and pressure when the wellboreintervention tool system 10 is not in use. -
FIG. 2A shows the wellboreintervention tool system 10 in more detail. The wellboreintervention tool system 10, hereinafter “tool” for convenience, may include a self-containedpower supply 10E such as batteries within a pressure sealedhousing 11. A control andpower module 10F disposed in thehousing 11 may be used to operate awellbore intervention device 10A. In the present embodiment, the wellbore intervention device may be a scale removal device disposed proximate the bottom of thehousing 11. The scale removal device may be any type known in the art, including a chemical storage and release mechanism, motor-rotated blades or abrasive mills, electric shock (sparker) discharge devices, acoustic devices, heater(s) to remove paraffin deposits, or any other such device for removal of deposits in the tubing (12 inFIG. 1 ). Thetool 10 may include combinations of any or all of the foregoing as well. Thetool 10 may include apropulsion device 10G, such as a fluid operated jet or a propeller to cause thetool 10 to move within thetube 14 during operations if gravity is insufficient to move thetool 10 downwardly to the depth of any obstruction, and to return thetool 10 to the lubricator system (22 inFIG. 2 ) if fluid flow from the well is insufficient to lift thetool 10. Thehousing 11 may includeannular seals 10D such as swab cups to enable free movement of thetool 10 downwardly, but may seal to engage the interior of the tubing (14 inFIG. 1 ) to enable fluid flow into the well to lift the tool into the lubricator system (22 inFIG. 2 ). The upper end of thehousing 11 may include amating latch 10B to engage the latch (22E inFIG. 2 ) in the lubricator system sealing cover (22D inFIG. 2 ). Thehousing 11 may includecentralizers 10C to enable relatively free movement of thetool 10 in the tubing (14 inFIG. 2 ) and to keep thetool 10 centered in the tubing for proper operation of the scale removal device. - Scale or paraffin build up may be indicated within the production tubing (14 in
FIG. 2 ), for example, by a decrease in fluid production from the well. Thus it may be necessary to deploy thetool 10. Thetool 10 may be installed into the lubricator system (22 inFIG. 2 ) prior to installing the lubricator system (22 inFIG. 2 ) onto the wellhead (20 inFIG. 2 ) or thetool 10 may be installed into the lubricator system (22 inFIG. 2 ) by unlatching and removing the sealing cover (22D inFIG. 2 ). Retrieval of thetool 10 may be performed by unlatching and retrieving the entire lubricator system with thetool 10 inside the lubricator system, or by unlatching the sealing cover (22D inFIG. 2 ) and retrieving thetool 10. It is also possible to perform tool replacement using an ROV in marine operations where the wellhead is on the water bottom. - In other embodiments, the
wellbore intervention device 10A may be any other type of wellbore tool, including, without limitation, a production logging instrument, a plug or packer setting tool or a video camera. -
FIG. 2 shows thetool 10 engaged with thelatch 22E and theisolation valves 22A andpressure equalization valves 28 closed so that the well can operate normally. When it is determined that deployment of the tool is necessary,FIG. 3 illustrates that thepressure equalization valves 28 may be opened to equalize pressure in the well with the pressure in thelubricator system 22. Theisolation valves 22A may then be opened and thelatch 22E may be released to enable thetool 10 to move downwardly through thewell tubing 14. Movement of thetool 10 into the wellbore may be by gravity or by a propulsion device (10G inFIG. 2A ) in thetool 10. It is also here illustrated that the tool performs scale or paraffin removal. -
FIG. 4 illustrates that one or both of the isolation valves28 has been closed, so that well can be flowed at low rate with thetool 10 being in the wellbore. Scale or other deposit removal may then be started by operating thedeposit removal device 10A. When thetool 10 reaches the area of restriction caused by scale or paraffin, thetool 10 performs the removal of this restriction as explained above. As the deposits are removed and the flow restriction is alleviated, thetool 10 will by move further down into the wellbore by gravity (or by use of thepropulsion device 10G inFIG. 2A , e.g., for highly inclined or horizontal wells) Thetool 10 control and power module (10F inFIG. 2A ) may include an internal mechanism that detects length of free fall, e.g., integrating accelerometers or an integrating velocity meter and/or area with no unwanted restriction. The power and control module may be programmed to enable thetool 10 to stop itself, e.g., by energizing its swab cups (10D inFIG. 2A ), a mechanical breaking mechanism or the propulsion device (10G inFIG. 2A . - A device preventing the
tool 10 from going further into the wellbore than a selected depth may also be installed in the wellbore, for example, a narrow internal diameter packer or similar restriction. Such a device can be set up to trigger the power and control module (10F inFIG. 2A ) to cause thetool 10 to return the lubricator/system 22. An example of such device may be a contact switch, shown at 13 inFIG. 2A which would not be triggered by scale or other deposits, but would be triggered by contact with a packer or similar internal diameter restriction. -
FIG. 5 illustrates that thetool 10 is transported up-hole, either by producing the well at low flow rate or by the propulsion device (10G inFIG. 2A ). Theisolation valves 28 are opened to enable thetool 10 to enter thelubricator system 22. -
FIG. 6 illustrates that thetool 10 has latched into thelubricator system 22 on thelatch 22E in the sealingcover 22D. At such time theisolation valves 28 may be closed and the well brought back to normal production. Thetool 10 is now coupled to the electrical coupler (part oflatch 22E) in the sealingcover 22D so that the batteries (10E inFIG. 2A ) can be charged. In some embodiments it may be possible to retrieve logged data and transmit new commands to thetool 10 through theelectrical connector 22F. - After the
isolation valves 28 are closed, pressure inside thelubricator system 22 may be released using thepressure relief valve 24. Such may be performed prior to any required removal of thesealing cap 22D or thelubricator system 22 from thewellhead 20. - While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.
Claims (19)
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US15/508,916 US20170204702A1 (en) | 2014-08-19 | 2015-07-14 | Battery operated autonomous scale removal system for wells |
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US201462038930P | 2014-08-19 | 2014-08-19 | |
PCT/US2015/040262 WO2016028412A1 (en) | 2014-08-19 | 2015-07-14 | Battery operated autonomous scale removal system for wells |
US15/508,916 US20170204702A1 (en) | 2014-08-19 | 2015-07-14 | Battery operated autonomous scale removal system for wells |
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US (1) | US20170204702A1 (en) |
EP (1) | EP3183413A4 (en) |
WO (1) | WO2016028412A1 (en) |
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CN108131118A (en) * | 2016-11-30 | 2018-06-08 | 中国石油天然气股份有限公司 | Test drifting integrated tool |
WO2019038557A1 (en) | 2017-08-25 | 2019-02-28 | Expro North Sea Limited | Autonomous systems and methods for wellbore intervention |
WO2019118666A1 (en) * | 2017-12-14 | 2019-06-20 | Downing Wellhead Equipment, Llc | Subterranean formation fracking and well workover |
CN110608013A (en) * | 2019-09-30 | 2019-12-24 | 南华大学 | Ultrasonic descaling device and method for in-situ leaching production well |
US10662740B2 (en) | 2016-04-14 | 2020-05-26 | Downing Wellhead Equipment, Llc | Valve apparatus |
WO2021199000A1 (en) * | 2020-04-02 | 2021-10-07 | Brown Owunari | Dewaxer flow enhancer system and method |
US11256273B2 (en) * | 2020-07-08 | 2022-02-22 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
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US10662740B2 (en) | 2016-04-14 | 2020-05-26 | Downing Wellhead Equipment, Llc | Valve apparatus |
US11072995B2 (en) | 2016-04-14 | 2021-07-27 | Downing Wellhead Equipment, Llc | Valve apparatus |
CN108131118A (en) * | 2016-11-30 | 2018-06-08 | 中国石油天然气股份有限公司 | Test drifting integrated tool |
WO2019038557A1 (en) | 2017-08-25 | 2019-02-28 | Expro North Sea Limited | Autonomous systems and methods for wellbore intervention |
US11293266B2 (en) | 2017-08-25 | 2022-04-05 | Expro North Sea Limited | Autonomous systems and methods for wellbore intervention |
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WO2019118666A1 (en) * | 2017-12-14 | 2019-06-20 | Downing Wellhead Equipment, Llc | Subterranean formation fracking and well workover |
US10689938B2 (en) | 2017-12-14 | 2020-06-23 | Downing Wellhead Equipment, Llc | Subterranean formation fracking and well workover |
CN110608013A (en) * | 2019-09-30 | 2019-12-24 | 南华大学 | Ultrasonic descaling device and method for in-situ leaching production well |
WO2021199000A1 (en) * | 2020-04-02 | 2021-10-07 | Brown Owunari | Dewaxer flow enhancer system and method |
US11256273B2 (en) * | 2020-07-08 | 2022-02-22 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
Also Published As
Publication number | Publication date |
---|---|
EP3183413A4 (en) | 2017-08-02 |
EP3183413A1 (en) | 2017-06-28 |
WO2016028412A1 (en) | 2016-02-25 |
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