WO2009093912A1 - Procédé et an appareil pour commander une barrière de puits - Google Patents

Procédé et an appareil pour commander une barrière de puits Download PDF

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Publication number
WO2009093912A1
WO2009093912A1 PCT/NO2009/000025 NO2009000025W WO2009093912A1 WO 2009093912 A1 WO2009093912 A1 WO 2009093912A1 NO 2009000025 W NO2009000025 W NO 2009000025W WO 2009093912 A1 WO2009093912 A1 WO 2009093912A1
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WO
WIPO (PCT)
Prior art keywords
well
fluid
barrier
activating
plug
Prior art date
Application number
PCT/NO2009/000025
Other languages
English (en)
Inventor
Bård Martin TINNEN
Håvar SØRTVEIT
Original Assignee
Well Technology As
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Well Technology As filed Critical Well Technology As
Priority to EP09703600.8A priority Critical patent/EP2245261B1/fr
Priority to US12/864,572 priority patent/US20100307773A1/en
Publication of WO2009093912A1 publication Critical patent/WO2009093912A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
    • E21B33/1295—Packers; Plugs with mechanical slips for hooking into the casing actuated by fluid pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 boreholes or wells
    • E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs

Definitions

  • This invention regards a system and a method related to Remote Activated Downhole Tools and Devices used in association with wells for the production of hydrocarbons. More specific, the invention regards a method and an apparatus for control- ling a well barrier arranged for being run into a well to separate a first well zone from a second well zone by a sealing element .
  • Wells for the production of hydrocarbons are designed in a range of different ways, depending on a number of influencing factors. Such factors include production characteristics, safety, well servicing, installation- and re-completion issues, downhole monitoring and control requirements and com- partmentalisation of producing zones.
  • This patent application regards downhole devices, in particular, barrier elements such as plugs, packers and valves that are applied for varying tasks during the construction and servicing of wells.
  • plugs and packers refer to a range of zonal isolation devices. When referring to a “plug” and a “packer”, respectively, there is room for confusion, as the terms tend to be mixed.
  • a plug is normally referred to as an isolation device that seals both in the annular space between the plug and the wellbore as well in the centre of the plug itself.
  • a packer is normally referred to as an isolation device that seals in the annular space between the packer and the wellbore, but not in the centre of the packer itself.
  • packer is often used in conjunction with inflatable packers, where a liquid is pumped into the sealing element in order to inflate this and create a seal between the inflatable packer body and the inner bore of the production tubular.
  • Inflatable packers are not as frequently applied as the more standard plugs and packers applying compression set elastomer elements, and in some more exotic versions, expandable metal-to- metal seals.
  • Many wells in particular offshore wells, include a production packer in the lower section of the production tubular.
  • the production packer is mainly for safety issues, in order to provide a barrier against the highly pressurised fluids in a hydrocarbon reservoir.
  • Plugs and packers are commonly used in connection with compartmentalisation of reservoir zones, in order to enable a future zone isolation of certain producing intervals .
  • Plugs and packers are also used in connection with intervention operations, to isolate sections of the well, to hang off other devices and similar purposes. Plugs and packers used to isolate sections of the well are often referred to simply as “plugs” .
  • a certain type of specialised packers, referred to as “straddle packers”, comprising two isolation elements, are used for isolation of upper and/or intermediate production zones, while still allowing for production from lower lying zones through a centre bore in said straddle packer.
  • Plugs and packers can have useful applications through- out a wells life cycle, and can be installed (and removed) on drill pipe, on the completion string itself or using well servicing techniques such as wireline, coil tubing or snubbing.
  • the downhole safety valve is mainly for safety issues to provide a barrier element between the high- pressurised reservoir and the atmospheric surround- ings .
  • Circulation valves are used to provide such as flow access between the production tubular and the annular conduit between the production tubing and the surrounding casing, to displace from one fluid type to another fluid type, often in connection with the completion and eventual recompletion of the well. Similar valves are also utilised in connection with the injection of fluids such as scale inhibitors to prevent salt deposits in the production tubular.
  • Zone control valves Many wells penetrate multiple reservoir sections. The production profile of differ- ent reservoir sections might deviate significantly with respect to pressure, flow rate, fluid type and similar. Zone control valves are used to open/close access to zones and, in some instances, to regulate flow by means of a variable flow access through the valve body.
  • well design can comprise a range of components, such as permanently installed monitoring devices and artificial lift systems.
  • barriers such as temporary barriers in the said well. Such barriers could be interven- tion plugs and/or disappearing plugs and/or valves. Temporary barriers can be used to isolate existing producing intervals, to enable investigation and service and/or opening of other producing zones in the said well. At later stages such barriers might be removed to regain communication with the origi- nal producing zone, to regain production from the said zone or to open the said zone to enable injection of fluids and chemicals to enhance the producing capabilities of the said well or other wells producing from the same reservoir zone.
  • a multilateral well is a well with several "branches" in the form of drilled bores that origin from a main bore. The method enables a large reservoir area to be drained by means of one well.
  • a side track well is typically an older production well that is used as the basis for drilling one/multiple new bores. Hence, only the bottom section of the new producing interval needs to be drilled, hence time and costs are saved.
  • Smart well completions are typically applied in wells with several producing and/or injecting zones and/or wells with several bores (i.e. multilateral wells).
  • Such smart well completion components consist of a series of monitoring systems and/or flow control valves which can be used to monitor and control production from each producing interval in the well or injection into each interval in the well.
  • Such smart well monitoring systems and valves are normally operated remotely through hydraulic and/or electric communication (and in some cases partly fibre optic) lines that run all the way from the lower (reservoir) section of a well to the surface.
  • smart well valves can also be manipulated by an intervention operation (such as coiled tubing, wireline, or slickline) , should the control line based activation systems for some reason fail to operate.
  • Smart well valves may comprise on/off valves (i.e. either fully open or fully shut) as well as variable opening chokes/flow control valves.
  • New well designs such as the ones described above have in a number of cases entailed a new challenge in the form of in- accessible areas of the well. In particular, this may apply for multilateral wells and sidetrack wells.
  • it is normally deemed as non-desireable to perform interventions in the side branches of the well as the risk of getting stuck in the junction between branches and/or causing other types of damage to the well are perceived to be of too high a risk, or the branches simply being physically impossible to enter (in any acceptable, controllable manner) .
  • Packers and/or plugs - Fill related challenges Common well operations involve the use of a packer or plug to isolate a zone or to hang off equipment such as data acquisition devices or flow control devices. Fill material resulting from the production of other (higher located) producing zones or from the drilling of a sidetrack or from a cleanout of the well may precipitate onto the packer or plug, such that mechanical profiles for the equalising and/or retrieval of the packer or plug become inaccessible. As a result retrieving tools cannot be engaged properly with the packer or plug, as required to equalise and/or retrieve the packer or plug.
  • Scaling i.e. salt deposits in the wellbore
  • Scale may occur in the packer or plug and cause similar problems as described above.
  • Scale might also entail fill problems as described in point 1 above, as scale might loosen from parts of the wellbore and fall down onto the plug/packer in question.
  • scale may also form restrictions in the wellbore, narrowing down the inner diameter of the tubular, and preventing well servicing operations due to servicing tool not being able to get through the scale caused restric- tion.
  • Valves - damage to hydraulic and electric control lines A valve or set of valves intended for flow control and/or circulation purposes may installed in a well. If the well is a smart well, the valve or set of valves are linked to surface via a hydraulic and/or electric (or fibre optic) 5 control line required to operate the said valve or set of valves. During installation and/or during the life of the well such control lines may become damaged and as a result the valve or set of valves cannot be operated in normal manner or not at all. As a result important operationalo requirements cannot be performed in the said well.
  • Wireline bailing implies the running of small suction pump devices on wire, an operation that normally entails a. large number of trips in the hole and consequently a long operational time. Circulation of liquids are used to attempt washing out fill materials obstructing the mechanical design features required to retrieve the packer or plug. All the known methods as described above may be of high cost .
  • valve or set of valves can be operated by means of an intervention operation such as coiled tubing or wireline. This is high cost operations for such operation of valves, and the operational flexibility becomes very limited as a result.
  • the objective of the invention is to provide a novel and alternative system to add functionality and redundancy to the operation of downhole mechanical devices such as packers, plugs and valves.
  • An entailing objective of the invention is to provide alternative, preferably stand-alone solutions to the operations of plugs, packers and valves associated with wells- for the production of hydrocarbons.
  • a method for controlling a well barrier arranged so as to be able to be inserted into a well for allowing a first well zone to be separated from a second well zone by means of a sealing element
  • the method comprises setting a pressurized fluid in communication with an activating element by selec- tively controlling an opening device, and wherein the acti- vating element influences opening of the sealing element to provide communication between said first and second well zones
  • the method further comprises the step of influencing the pressurized fluid supplied to the activating element by the well pressure upstream or downstream of the sealing element.
  • the opening device is controlled by wireless signals.
  • the wireless signals are transmitted from a transmitter located at a surface of the well.
  • the wireless signals are transmitted from a tool being inserted into the well.
  • the tool is normally run into the well after installation of the well barrier. However, the tool may alternatively be run into the well prior to installation of the well barrier.
  • the receiver system has transceiver capabilities, and so has the said transmitter system.
  • the wireless signals could be wireless signals by means of pressure or al- ternative variations in the wellbore fluids, as acoustic signals in fluid or conduit pipe, as electromagnetic signals or other wireless signals.
  • a set of operations such as the operation of one or a series of system components is initiated, for example the op- eration of a downhole motor which again operates a piston opening a channel in the packer or plug, which will equalize pressure over the packer or plug and/or open channels in the packer/plug in order to allow any fill material to fall down through the packer or plug.
  • Patent application NO 20061275 owned by the applicant for this patent, describes a signal transmission system and method for applying such wireless signals to a downhole device and is incorporated herein by reference.
  • the activation signal is not wireless, but a direct connection of nature.
  • the signal transmission link could be a fibre optic line.
  • the signal transmission link could be electric or hydraulic lines. Typically, the latter cases would include situations where downhole components are installed so deep that an electric or hydraulic line cannot transfer the re- quired energy to operate downhole components, but that communication signals still can be transmitted.
  • said pressurized fluid is the well fluid located upstream or downstream of the sealing element.
  • said pressurized fluid is a fluid located within an accumulator chamber influenced by the well fluid, but wherein the fluid within the accumulator chamber is separate from the well fluid.
  • the fluid within the accumulator chamber is pre-compressed to a pressure lower than the well pressure at a working depth, and prior to inserting the well barrier into the well.
  • a well barrier for use in a well for production of hydrocarbons, the well barrier being arranged for installation in the well for allowing a first well zone to be separated from a second well zone by means of a sealing element, wherein an activating element is arranged for influencing the sealing element to provide communication between said first and second well zone, wherein the activating element is arranged to be initiated by the pressure in an activating fluid that is supplied to the activating element by a controlled opening device, the pressure in the activating fluid being influenced by the well pressure upstream or downstream of the sealing element .
  • the activating fluid is well fluid that is communicated via a channel from the well upstream or downstream of the sealing element to the activating element.
  • the activating fluid is a fluid located in an accumulator chamber separate from the well fluid, the volume of the accumulator chamber being influenced by the well pressure upstream or downstream of the sealing element.
  • said opening device includes a receiving means, at least one energy source and a driving means.
  • each of the receiving means and the driving means is powered by an energy source of their own.
  • the energy sources have different characteristics.
  • a downhole packer and/or plug is equipped with various components required to receive an activation signal followed by operation of one or a series of components, as for example operation of a downhole motor which again operates a screw attached to a piston, which will equalize pressure over the packer or plug, open the plug so that fill can be transported through it and actively loosen any packed fill material allowing it to fall down through the packer or plug.
  • the active loosening of packed fill material might be achieved by means of mechanical components such as transport screws, or alternative components such as vibrating components .
  • a downhole packer and/or plug is equipped with various components required to receive an activation signal followed by operation of one or a series of components, as for example operation of a down- hole motor which again operates a piston covering a communication channel between the upper and lower sides of the packer or plug, which will equalize pressure over the packer or plug.
  • a downhole vale or set of valves is equipped with various components required to receive an activation signal followed by operation of one or a series of components, as for example operation of a down- hole motor which again operates a valve to a desired position.
  • Figure 1 shows a simplified example of one embodiment of the invention
  • Figure 2 shows examples of preferred general system features for a generalised embodiment of the invention
  • Figure 3 shows one specific example of setting a packer ele- ment by means of a communication, activation and powering system built into the wall of an annular shaped well tool
  • Figure 4 shows an example of operating (equalising and/or opening) a well servicing packer that is covered by- well debris;
  • Figure 5 shows- an alternative example of operating (equalis- ing and/or opening) a well servicing packer that is covered by well debris;
  • Figure 6a shows even another alternative example of operating (equalising and/or opening) a well servicing packer that may be exposed to well debris (not shown) ;
  • Figure 6b shows a section taken through line A-A in fig. 6a
  • Figure 7 illustrates one major problem related to well servicing packers being covered by well debris,-
  • Figure 8 shows the first step of an example of operating
  • Figure 9 shows the second step of an example of operating
  • Figure 10 shows how one preferred modular embodiment of the invention, comprising a communication and activation system, is interfaced towards a well servicing packer in one end, and a disintegrating plug in the other end, and how such embodiment of the invention is interfaced and utilised to remove said disintegration plug,-
  • Figure 11a shows one example of mechanical design features for a system intended for operating (equalising and/or opening) a well tooling device according to one embodiment of the invention
  • Figure lib shows a section taken through line B-B in fig. 11a;
  • Figure 12a shows another example of mechanical design features for a system intended for operating (equalising and/or opening) a well tooling device according to one embodiment of the invention
  • Figure 12b shows a section taken through line C-C in fig. 12a
  • Figure 13 shows another example of mechanical design features for a system intended for operating (equalising and/or opening) a well tooling device according to one embodiment of the invention.
  • Figure 14 shows a plug pulling tool that also comprises a wireless transmitter and/or receiver.
  • Figure 1 illustrates an example of operating according to the invention.
  • a downhole device 102 is installed.
  • Such device could be a plug, a valve or other types of downhole device.
  • the downhole device is associated with a signal receiver 103 and an activation system 104.
  • a wireline 105 and associated toolstring 106 is used to deploy a signal transmitter 107 into the well 101.
  • the well comprises a well section that is available for intervention 108 and a well section that is non-available for intervention 109.
  • the toolstring 106 may be equipped with a well- bore anchor 110.
  • This said anchor 110 may be necessary to assure stability of the transmitter 107 during operation in order to impose an optimum signal into the primary signalling medium (the well fluid) and/or a secondary/complementary signalling medium (the steel tubing of the well 101) .
  • the transmitter 107 is designed for producing a signal with sufficient strength to overcome obstacles related to solids 5 and/or liquids as well as well geometries with poor signal carrying (for instance acoustic signal carrying) properties.
  • Figure 2 illustrates a generic design of the downhole device 102.
  • the tubular of the well is not shown.
  • the signal receiver 103 and activation system 104 are illustrated as modular,o somewhat external components, but could in other embodiments be fully incorporated in the main body of downhole device 102. The opposite applies for all components illustrated to be within the body of downhole device 102. In alternative embodiments, one or more of such components could be modulars and/or external modules if such are required to facilitate such as easy production, assembly, operation and maintenance of the overall system.
  • the signal receiver 103 of the downhole device 102 and other relevant systems are proposed powered by an energy generator 201 that, for most perceivable situations is combined with an energy storage and distribution unit 202 such as a re-chargeable battery with associated steering electronics.
  • an energy generator 201 that, for most perceivable situations is combined with an energy storage and distribution unit 202 such as a re-chargeable battery with associated steering electronics.
  • the energy generator 201 and energy storage and distribution unit 202 can be replaced by conventional non- rechargeable batteries. This is expected to become a commonly applied embodiment of the invention.
  • the activation system 104 Upon receiving an activation signal at signal receiver 103, the activation system 104 is initiated. In one embodiment of the invention, the activation system 104 initiates a desired operation directly. In other embodiments of the invention, the activation system initiates desired operations through an electronic logic 203. This could for example be the case if one or more internal components of downhole device 102 that are meant to be either addressed and/or activated in certain desired sequences, or if several autonomous devices 102 with different signal addresses are located at various locations in the well. Further to figure 2, the following system 102 modules and functions are within the scope of the invention:
  • Activating elements 204 In one embodiment of the inven- tion, this is a motor driven actuator system that is used to operate/activate a mechanical device, for example a pressure equalising device associated with a plug. In other embodiments of the invention, such activation element (s) 204 could be explosive detonators, charged gas chambers, pilot valves and/or other sub-systems
  • buttons, screws, gears, pressure boosting chambers, any- cascading electrical/mechanical system applied to initiate/activate/execute the operation of devices/elements (such as a sealing element) of downhole device 102.
  • Device/element to be operated 206 this could be a mechanical equalising device for a plug.
  • (Secondary) power source (s) 205 This is a power source (s) with the capacity to provide significant amounts of energy in order to do a power consuming operation such as the operation of the device to be oper- ated 206 as described above.
  • the need for a secondary power source is believed to be detrimental for system functionality, as neither power generators and re- chargeable batteries nor conventional non-rechargeable batteries are perceived to be able to provide sufficient energy to operate the device 206 and other relevant high-energy system components in all relevant cases.
  • the (secondary) power source 205 is a thermal battery. Thermal batteries are "dormant" high-power batteries that are activated by- means of operating a small detonator (explosive cap) .
  • thermal batteries When activated, thermal batteries normally have a life-o time less than 24 hours, but with the capacity of massive energy supply during that limited lifetime. Hence one or multiple thermal batteries will form a good secondary power source 205 in order to design a downhole device 102 with the capacity of performing a number ofs subsequent operations, especially if there is a time lag exceeding 24 hours between respective operations.
  • the secondary power source 205 comprises pyrotechnical materials or high pressure gases or atmospheric chambers, radioactiveo sources or other power sources .
  • the secondary power source 205 comprises a combination of two or more types and/or amounts of said power sources .
  • the downhole device 102 comprises a confirmation transmitter 207 that emits a signal as a confirmation that a desired operation is effectuated.
  • This signal can then be read by receiving systems incorporated in related well tooling (106, 107) or located ono the surface.
  • Such signal could be a wireless signal by means of pressure or alternative variations in the well- bore fluids, as acoustic signals in fluid or conduit pipe, as electromagnetic signals or other wireless sig- nals transmitted to a receiver node located at surface or another location in the wellbore.
  • such signal could be a signal transmitted in a fibre optic, electric, hydraulic or other line connection to a receiver node located at surface or another location in the wellbore.
  • confirmation of executed operation could also be verified by monitoring parameter changes that are related to the activation process, such as pressure changes, noise, and other physical changes.
  • confirmation is confirmed by the release of a physical object from the downhole device 102.
  • the downhole device 102 comprises a data acquisition system 208. Such data could comprise downhole pressure, temperature, flow rate, fluid properties as well as other relevant downhole measurements known to those skilled in the art.
  • the downhole device 102 upon re- ceiving an activation command, uploads acquired data by means of the transmitter 207.
  • the downhole device 102 could represent an autonomous data acquisition device located in a non-accessible area of a well, for example in a branch of a multilateral well, that at regular and/or commando- determined intervals uploads data. For a branch installed downhole device 102, such data would typically be uploaded by means of a wireless signal to a receiver node located at surface or another location in the well- bore, or related well tooling (106,107).
  • the downhole device 102 and accessories represents the following important characteristics :
  • the downhole device 102 can lay "dormant" in the well, awaiting an activation command whilst spending an absolute minimum of energy, preferably below a level where an energy generator 201 can provide equal to or larger amounts of energy than what the monitoring 103 and activation 104 components consume.
  • the downhole device 102 is capable of meeting requirements to long system life combined with high power consuming operation capabilities.
  • Figure 3 illustrates one specific way and a preferred embodi- ment for designing a downhole device 102 in order to energize and operate a device/element 206 (the given example yields a packer element 310 to be set) .
  • This example applies in the case where all system components associated with downhole de- vice 102 has to be mounted inside the wall section 306 of a tubular (or other shaped) element. This could be the case if there is a strict need to provide an open centred area of the downhole device 206, which could be the case for devices such as (straddle) packers, smart-well valves etc.
  • the receiver sensor 302 reads a received wireless setting command 301.
  • the receiver sensor 302 is interrogated by a receiver electronics module 303 in order to interpret registrations from the sensor/receiver 302.
  • a receiver electronics module 303 When there is a positive detection of an activation signal, i.e. an initiating corn- mand, the electronics 303 emit a signal/impulse to fire a detonator 304 that again ignites a pyrotechnic charge 305 that is moulded to fit inside a slot in the wall 306 of the downhole device 102. As the pyrotechnic charge 305 burns, it generates pressurised gas that imposes a large pressure on the piston 307.
  • the piston 307 is forced downwards, and pushes hydraulic oil 308 which again forces a wedge-shaped element 309 downwards and forces this to compression-expand a packer element 310 and forces this to set against the tubing wall 311.
  • the wedge shaped element 309 is re- placed by means of an alternative element (s) with similar function - i.e. to compress the bottom packer element 310.
  • the receiver sensor 302 and associated electronics module 303 is powered by means of a power module 312 such as a battery.
  • the dotted line 313 illustrates the centre of the downhole device 102, indicating that the described system components are located inside the wall 306 of the downhole device 102 housing.
  • figure 3 this only illustrates one of a variety of ways of designing a system that sets in this case a packer element 310 or operates any general device/element 206 of a downhole device 102 further to the general methods described herein. Also, those skilled in the art will appreciate that figure 3 merely serves as a principle sketch and that exact system and method details may vary.
  • valve/barrier opens or "disappears" in other manners upon a finalised setting of the bottom packer element.
  • FIG. 4 illustrates the system for another embodiment of the invention.
  • the tubular of the well is not shown.
  • a plug or packer assembly 400 comprising a plug or packer 401 attached to an actuator sub 402.
  • the actuator sub 402 is made modular, to be attached to the plug or packer 401.
  • the internal of the plug or packer 401 is filled with some type fill material 403, being any fill material expected in a well related to the production of hydrocarbons.
  • the actuator sub 402 comprises a ("listening") sen- sor 404, a power device 405 such as a battery, an electronic section 406, an electrical motor 407, a gearbox 408, a sealing cone 409, and a nipple profile 410.
  • the (“listening") sensor 404 is a piezoelectric disc, an accelerome- ter, a radio antenna or a magnetostrictive material.
  • the actuator sub 402 Prior to installation the actuator sub 402 is attached to the plug or packer 401, and the sealing cone 409 provides a pressure seal against the nipple profile 410.
  • the assembly 400 is installed in a well. Before the assembly 400 is to be re- trieved the actuator 402 is operated. This is achieved as follows: An activation signal, such as a wireless signal, is transferred from a distant transmitter through a media such as the wellbore and/or the wellbore fluids, and picked up by the listening sensor 404.
  • the electronic section 406 inter- prets all signals picked up by the sensor 404.
  • the electronic section 406 Upon receipt of the correct activation signal the electronic section 406 will activate the electrical motor 407 to move the sealing cone 409 downwards. This operation will result in that pressure is equalized across the assembly 400, and allow the fill material 403 to fall down through the assembly 400.
  • the gearbox 408 may be required to generate sufficient force to move the sealing cone 409 downwards.
  • the complete system is powered by the power device 405. When this operation is completed the internal section of the plug assembly will be clean and ready to be retrieved by standard practises.
  • figure 4 merely serves for the purpose of illustrating the idea behind the invention.
  • Alternative design variations may apply.
  • the following items and functions may vary:
  • a sealing cone 409 as described might not be sufficient to provide a reliable stand-alone pressure seal both ways.
  • such sealing cone or similar system feature might be replaced or supplemented by alternative valve systems as known per se .
  • one part of such valve systems could have the purpose of holding the required pressure whereas another part of such valve system could have the purpose of preventing fill from entering the pressure containing part of the valve system, hence add risk to the operation of such valve system.
  • the operation of the actuator sub 102 may comprise numerous sequential steps, and the actuator sub 102 may comprise numerous subs system components (by means of power sources, acti- vating elements and other components) in series and/or parallel in order to achieve a successful operation.
  • one system module could operate a valve system to equalise pressure.
  • such valve system is located in a "clean" area of the plug.
  • a secondary system module could be operated to open the flow-by area of the plug or packer in such a manner that fill could fall down and through said plug or packer (i.e. all sensitive "clean area” modules are operated successfully prior to exposing these to fill or other pollutants from the "unclean” area) .
  • a plug/packer concept as shown in figure 4 may be designed to fit for operations with new, specialised pulling tools. I.e. such pulling tools could be equipped with signal transmitting capabilities in addition to general features required for the pulling of a plug/packer. In that way, one would not need two separate runs to pull the plug/packer as could be the case further to today' s methods and philosophies (i.e. one run on electric wireline to remotely equalise/open the plug and one run on mechanic wireline to pull the plug) . The same philosophy will apply for alterative embodiments and applications such as but not limited to shifting tools for valves .
  • Figure 5 illustrates an overall system for another embodiment of the invention.
  • the tubular of the well is not shown.
  • the main difference from figure 4 is the inclusion of a transport screw 501.
  • the actuator 402 is operated by means of an activation signal from a remote transmitter.
  • the signal is picked up by the listening sensor 404.
  • the electronic section 406 interprets all signals picked up by the listening sensor 404.
  • the electronic section 406 Upon re-
  • a gearbox 408 may be required to generate sufficient force to move the sealing cone. Further, independent and/or multiple motor/gear systems might be applied to operate the cone 409 and transport screw 501, respectively. The complete system is powered by the power device 405. When this operation is completed the internal section of the plug assembly will be clean and ready to be retrieved by standard practises .
  • figure 5 is merely given to describe an idea, and does only describe one of a number of possible embodiments. Alternative design variations may apply, and the additional comments given in the explanation to figure 4 also applies here.
  • FIG. 6a illustrates an overall system for yet another em- bodiment of the invention.
  • the tubular of the well is not shown.
  • a plug or packer assembly 400 comprising a plug or packer 401 attached to an actuator sub 402.
  • the actuator sub 402 comprises a listening sensor 404, a power device 405 such as a battery, an electronic section 406, an electrical motor 407, a gearbox 408, a perforated section 601, and a piston 602.
  • the perforated section 601 may be only a channel from the inside (centre) of the actuator sub 402 to the outside (annulus towards production tubing) .
  • the actuator sub 402 Prior to installation the actuator sub 402 is attached to the plug or packer 401, and the piston 602 provides a pressure seal against the perforated section 601.
  • the assembly 400 is installed in a well. Before the assembly 400 is to be retrieved the actuator 402 is operated. A remote signal is transferred through the wellbore and picked up by the sensor 404. The electronic section 406 interprets all signals picked up by the listening sensor 404. Upon receipt of the correct signal the electronic section 406 will activate the electrical motor 407 to move piston 602 upwards or downwards. This operation will result in that pressure is equalized across the assembly 400. The gearbox 408 may be required to generate sufficient force to move the sealing cone downwards. The com- plete system is powered by the power device 405. When this operation is completed the pressure is equalized and the plug assembly 400 can be retrieved by standard practises.
  • Fig. 6b shows a section of the actuator sub 402 taken through line A-A in fig. 6a.
  • Figure 7 illustrates one general problem related to well servicing packers being covered by well debris.
  • a plug pulling tool 701 is attempted attached to a plug 401 that has been installed in the well at an earlier instance.
  • the reason for installing plug 401 might as an example have been related to the isolation of producing zone 702 while servicing zone 703.
  • debris 704 has been released and fallen on top of plug 401.
  • the plug pulling tool 701 can not be engaged to the plug, and this might entail significant consequences with respect to subsequent costs and operational complexity to remedy the situation.
  • figure 7 only illus- trates one of numerous scenarios where a plug 401 or any other relevant tooling can not be operated as desired due to debris 704 or other well related problematic (corrosion, scale and other related problems) .
  • Figure 8 shows the first step of an example of operating (equalising and/or opening) a well servicing packer that is covered by well debris for a preferred embodiment of the invention.
  • a packer 401 is installed in a well by attaching it to the production tubular by means of methods as known per se.
  • the risk of debris or related problems has been perceived to be significant, hence a system according to a preferred embodiment of the invention has been attached to the bottom end of the plug - to overcome such problems.
  • the attached tooling comprises an outer housing 901 that contain flow channels 902.
  • the flow channels 902 are closed by means of a closure member 903 that is held in a preferred position by means of shear bolts 904. Further, the closure member 903 is attached to a shaft 905 that is connected to a piston 906 that is mounted inside a cylinder chamber 907.
  • Seals 908 ensure that the inside of the cylinder chamber 907 is kept at atmospheric pressure prior to the activation process to come.
  • a male ratch module 909 mounted on the shaft 905 corresponds with a female ratch module 910 mounted inside the cylinder 907.
  • a (“listening") sensor 911 is mounted at a convenient location of the tooling, in order to ensure as good signal re- ceiving capabilities as possible.
  • the sensor 911 is interrogated by electronics module 913 through a communication line 912.
  • the entire system is powered by battery 914.
  • Motor 915 is operated to retract motor shaft 916 from fluid channel 917.
  • Well fluid will then be able to flow into the tool via fluid channel 917.
  • Debris filter 918 is included to prevent particles and similar from plugging fluid channel 917 during operation.
  • Flow reducer 919 is included to prevent the system from being "shocked” to a state of damage due to the tremendous power released when opening an atmospheric chamber to the well pressure.
  • process bellows 921 ensures that the inside of the motor chamber 922 contains the same pressure as the well pressure. This entails that there is no thrust force acting on motor shaft 916 during operation, and that motor 915 can be operated on relatively low power.
  • the process bellows 921 is replaced by a piston, membrane or al- ternative pressure equalisation system.
  • Figure 9 shows the second step of an example of operating (equalising and/or opening) a well servicing packer that is covered by well debris for a preferred embodiment of the invention.
  • the closure member 903 has been pulled to the right (downwards) so that the channels 902 are opened.
  • debris can be removed either by falling down through channels 902, alternatively by producing the well through channels 902 in order to remove the debris.
  • closure member 903 has a conic shape and the channels 902 are made in a similar, tilted angle in order to facilitate particles falling down through the channels 902 (like as for an hour-glass) .
  • closure member 903 is reversible and in even other embodiments of the invention, the operation of opening and closing by means of closure member 903 is re- peatable .
  • Figure 10 shows how one preferred modular embodiment of the invention, comprising a communication and activation system, is interfaced towards a well servicing packer in one end, and a disintegrating plug in the other end, and how such embodiment of the invention is interfaced and utilised to remove said disintegration plug.
  • a sensor 911 is interrogated by an electronics module 913 powered by a battery module 914, and activation takes place by means of operating a member such as a motor 915 to open a fluid channel 917.
  • all modules are built into the wall of the tooling itself, in order to provide for a centre bore, which may be required to maximise the production of the well, or to facilitate the subsequent inter- vention of well service tooling through the shown system.
  • the operation of motor 915 causes wellbore pressure or alternative high pressure contained in a tool reservoir to access a removal mechanism 1003 of a disintegrating plug 1002.
  • removal mechanism 1003 may comprise a pressure activated detonation cap (ignitor) 1004 that set off a more powerful explosive charge 1005 in order to fulfil the plug element 1006 disintegration operation.
  • the tubular of the well is not shown.
  • a very distinctive feature shown in figure 10, and that forms part of a preferred embodiment of the system, is an accumulator, here in the form of a ring-shaped piston 1007 mounted inside an annular shaped piston chamber 1008.
  • the piston 1007 and piston chamber 1008 could have other forms and shapes than shown in figure 10, or be replaced by alternative design such as a membrane design.
  • the accumulator may comprise pressure-boosting features, such as differential areas on each side of the piston 1007. In the case where debris falls on top of the plug assembly, this entails the possibility of plugging of port 1009 which provides the access point for well fluids in order to undertake the removal of disintegration plug 1002. This could cause malfunction in the subsequent plug disintegration proc- ess.
  • the piston chamber 1008 is primed with fluid, e.g. a compressible gas, or air, prior to installation in the well.
  • the fluid within the accumulator chamber 1008 is pre-compressed to a pressure lower than the well pressure at a working depth, and prior to inserting the well barrier into the well.
  • this will reduce the requirements to volume of the accumulator space.
  • the accumulator chamber can be made significantly smaller than for the example using of a at atmospheric pressure.
  • the invention entail a far smaller safety risk than a system containing a gas chamber pre-compressed to pressures above the well pressure at working depth.
  • Figure 11 shows one example of mechanical design features for a system intended for operating (equalising and/or opening) a well tooling device according to one embodiment of the invention.
  • the tubular of the well is not shown.
  • fluid channels 601, intended to equalise and/or open a downhole tooling system are initially covered by a mandrel that forms part of a piston 602.
  • the piston 602 is held in place by an anchor 1101.
  • the anchor 1101 is fixed to the outer tool mandrel 1102 by methods known as per se such as welds 1103.
  • Long oval slots, illustrated by means of dotted lines 1104 and 1104' are made into mandrel 1102 in order for piston 602 to move longitudinally in a downward direction upon activation.
  • An anchor flange 1105 is used to hold the piston 602 in place, connected to the anchor 1101.
  • Cascade rings 1106 as known from parachuting and space shuttle applications are used to connect the anchor 1101 and anchor flange 1105, and tensioning bolts 1107 are used to make the connection firm at a desired tension.
  • Activation takes place by communication techniques as described herein.
  • a motor 1108 is used to release the cascade ring system 1106 whereupon the connection between the anchor 1101 and anchor flange 1105 is broken. Subsequently, the spring 1109 will extend and shift the piston 602 downwards so that fluid channels 601 are opened.
  • Figure 12 shows another example of mechanical design features for a system intended for operating (equalising and/or opening) a well tooling device according to one embodiment of the invention.
  • the tubular of the well is not shown.
  • the piston 602 is shifted downwards by means of operating pump 1201 so that fluid with a higher relative pressure than the surroundings is pumped into the closed chamber 1202.
  • the pump chamber 1203 is pre-filled with a fluid that the pump 1201 can handle in order to avoid pumping of well fluid, however in alternative embodiments of the invention, the pump 1201 could pump well fluids directly.
  • Piston 1204 is included to separate the clean fluid inside the pump chamber 1203 from the well fluids that are entering the system via channel 1205.
  • Figure 13 shows another example of mechanical design features for a system intended for operating (equalising and/or opening) a well tooling device according to one embodiment of the invention.
  • the tubular of the well is not shown.
  • a flapper valve 1301 is held in a fixed position by means of a lock ring 1302 on the lower side and a lock shoulder 1303 on the upper side.
  • the lock shoulder 1303 is attached to a lock cylinder 1304 that is attached to the outer housing 1305 by methods as known per se.
  • the lock ring 1302 is attached to a lock mandrel 1306.
  • the lock mandrel 1306 is attached to the " outer housing 1305 by means of a cascade ring system 1106 as illustrated in figure 11.
  • FIG. 14 shows a plug pulling tool 701 that also features a wireless transmitter and/or receiver 1401.
  • figure 14 shows a plug 401 that has been installed in the well at an earlier instance, the plug being associated with a wireless activable bottom sub 1402, with functionality such as to open channels between the well section above the plug and the well section below the plug upon receiving a wireless activation command.
  • the combination of a traditional pulling tool with a wireless transmitter/transceiver is of novel art and not known in the industry. The intention with this novel art pulling tool is to enable the opening and retrieval of the plug 401 during one intervention in the hole, rather than using one run in the hole for the wireless activation signal transmission and a second run in the hole for the physical attaching to the plug.
  • the invention both comprises modular design that interfaces towards 3 rd party tooling (such as plugs and/or packers) as well as total design where the parts encompassed by the invention are built into such tooling as a stand-alone product.
  • 3 rd party tooling such as plugs and/or packers

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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)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
  • Coating Apparatus (AREA)
  • Application Of Or Painting With Fluid Materials (AREA)

Abstract

La présente invention concerne un procédé permettant de commander une barrière de puits (401, 1002) agencée de façon à pouvoir être insérée dans un puits pour permettre à une première zone de puits d’être séparée d’une seconde zone de puits au moyen d’un élément d’étanchéité (409, 903, 1006), le procédé consistant à mettre un fluide sous pression en communication avec un élément d’activation (905, 906 ; 1004, 1005) en commandant sélectivement un dispositif d’ouverture (913, 914, 915), et l’élément d’activation (905, 906 ; 1004, 1005) influençant l’ouverture de l’élément d’étanchéité (409, 903, 1006) pour assurer une communication entre lesdites première et seconde zones de puits. Le procédé comprend en outre l’étape qui consiste à influencer le fluide sous pression fourni à l’élément d’activation (905, 906 ; 1004, 1005) grâce à la pression de puits en amont ou en aval de l’élément d’étanchéité (409, 903, 1006). La présente invention concerne également une barrière de puits (401, 1002) permettant la mise en œuvre du procédé.
PCT/NO2009/000025 2008-01-24 2009-01-22 Procédé et an appareil pour commander une barrière de puits WO2009093912A1 (fr)

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EP09703600.8A EP2245261B1 (fr) 2008-01-24 2009-01-22 Procédé et appareil pour commander une barrière de puits
US12/864,572 US20100307773A1 (en) 2008-01-24 2009-01-22 Method and an apparatus for controlling a well barrier

Applications Claiming Priority (2)

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NO20080452A NO20080452L (no) 2008-01-24 2008-01-24 A method and an apparatus for controlling a well barrier
NO20080452 2008-08-18

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ITUA20162927A1 (it) * 2016-04-27 2017-10-27 Eni Spa Sistema e metodo per il monitoraggio, il controllo e la messa in sicurezza di pozzi per l’estrazione di fluidi di formazione.
WO2017187368A1 (fr) * 2016-04-27 2017-11-02 Eni S.P.A. Système et procédé de surveillance, de commande et de sécurisation de puits pour l'extraction de fluides de formation
CN110741133A (zh) * 2017-04-12 2020-01-31 沙特***石油公司 用于密封井眼的***和方法
WO2019078982A1 (fr) 2017-10-16 2019-04-25 Baker Hughes, A Ge Company, Llc Obturateur formé à partir d'un matériau à désintégration à la demande (dod)
EP3698013A4 (fr) * 2017-10-16 2021-06-09 Baker Hughes, a GE company, LLC Obturateur formé à partir d'un matériau à désintégration à la demande (dod)

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US20100307773A1 (en) 2010-12-09
EP2245261A1 (fr) 2010-11-03
NO20080452L (no) 2009-07-27

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