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
  • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
  • E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes
• • 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
  • E21B33/02—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

Definitions

• the present invention concerns an injection module, a method and a use for lateral insertion and bending of a coiled tubing via a side opening in a well.
• the well may be a subsea well or a land-based well.
• the well may any type of well, for example a petroleum well, an injection well, a water well or a geothermal well.
• the side opening of the well may be connected to a well pipe, for example a production tubing, or an annulus between casings in the well.
• a well pipe for example a production tubing, or an annulus between casings in the well.
• the side opening will be connected to a pipe stub provided with a valve, for example a gate valve, or one or more meters, for example a pressure gauge, thermometer or similar.
• the background of the invention is in problems associated with undesirable pressure build-up especially in annuli, but also in well pipes, in underground wells. This pressure build-up results from associated pressure barrier failures in such wells.
• such pressure barriers consist of cement, well liquids, packers, plugs and casings.
• the purpose of such pressure barriers is to prevent undesirable leakage and flow of well fluids to the surface, but also to/from permeable formations
• Pressure barrier failure may arise in any phase of the lifetime of a well and, depending on the type of well and well phase, such a failure may cause various unfortunate and possibly disastrous consequences. Thus, pressure barrier failure constitutes a problem both in new and old wells, including old wells that have been plugged and abandoned.
• Fluid-conveying channels may also be formed in the cement in the annulus due to setting-related and/or earthquake-related movements in one or more formations surrounding a well. Such setting-related and/or earthquake-related movements may also damage packers, plugs and other well pressure counteracting equipment in a well and thus result in pressure build-up and possible fluid leakages in the well .
• Salt water and/or other corrosive fluids in a well may also disintegrate casings, packers plugs and similar in the well and eventually cause pressure build-up and possible fluid leakages in the well .
• a well pressure counteracting liquid for example d rilling mud containing weighting materials for increasing the density of the liquid, and which is positioned in an annulus/well pipe for some considerable time, may eventually segregate and deposit its weighting material. Thereby, the majority of the liquid will assume a smaller density and hence will lose its well pressure counteracting effect. This may then cause pressure build-up and possible fluid leakages in the well.
• pressure barrier failure may lead to shut-down of the production from the well. Pressure barrier failure may also result in undesirable fluid leakage to other permeable formations in the underground .
• a leakage in an oil well may cause oil to flow to a groundwater-permeable formation penetrated by the well so as to contaminate the water in the groundwater-permeable formation.
• squeeze cementing may also be carried out in the particular area of the annulus, or injection of a sealing material into the annulus may be carried out.
• a squeeze cementing tool or an injection tool must be inserted into a well pipe, for example a casing, located immediately inside of the particular annulus. At least one hole through the well pipe must also be formed before the squeeze cementing or the injection can be initiated.
• a remedying scab liner may be inserted into the casing and disposed in a pressure- sealing manner around the hole by means of suitable packers.
• the liner constitutes a pressure-tight casing patch for the casing.
• said problems related to pressure build-up in well pipes, and especially in annuli may be remedied to a large extent if a pressure-remedying fluid is conducted into the particular well annulus and further downwards to the problematic area of the annulus.
• US 5.927.405 describes an arrangement for remedying pressure build-up in an annulus in a well by inserting a flexible hose, for example a hose formed from an elastomer material, into the annulus via a gate valve and a side opening in a wellhead.
• a flexible hose for example a hose formed from an elastomer material
• the hose must be pressurized for rendering it sufficiently rigid to allow it to be displaced downwards in the annulus.
• the lower end of the hose is temporarily blocked by means of a nozzle, burst disc or similar which holds the pressure in the hose during the insertion.
• the pressure in the hose is increased until the nozzle opens or the burst disc breaks.
• said side opening in the wellhead is formed as a downwardly bent passage leading into the annulus for allowing the hose to be guided in a downward direction during the insertion thereof in the annulus.
• a hose guide bushing is used for this purpose. The hose guide bushing is screwed into a straight side opening in the wellhead and connects the annulus to the outside of the wellhead. Further, the hose guide bushing comprises a downwardly bent passage structured in a manner allowing it to guide the hose in a downward direction during the insertion thereof in the annulus.
• US 6.186.239 shows further details of such lateral insertion of a flexible hose in an annulus, including details of an injection system that is to push (inject) the hose into the annulus via said side opening in the wellhead.
• This injection system comprises, among other things, a blowout preventer ("BOP"), sealing elements and a cutting device for the hose.
• BOP blowout preventer
• US 6.186.239 describes an end fitting capable of being screwed into the side opening, and which may be connected to an upper end of the hose after being conducted into the annulus and the upper end of the hose being severed by means of said cutting device. By so doing, the hose may be left behind in the annulus for potential use later.
• a principal object of the invention is to provide a technical solution rendering possible to conduct a coiled tubing into a well via a side opening therein.
• Another object of the invention is to provide a technical solution rendering possible to conduct a fluid, for example a fluidized treatment agent into a well via a side opening therein, and by means of coiled tubing.
• a further object of the invention is to provide a technical solution which at least reduces one or more of the above-mentioned disadvantages of the prior art in order to prevent pressure build-up in a well.
• a more specific object is to provide a technical solution which, relative to known solutions, is relatively simple, flexible, compact and cheap, and which is space-saving and weight-wise light in use.
• an injection module for lateral insertion and bending of a coiled tubing via a side opening in a well
• the module is structured for connection to the side opening, and wherein the module comprises injection equipment for coiled tubing operations.
• the distinctive characteristic of the injection module is that it also comprises an insertion device connected to said injection equipment;
• the insertion device is structured in a manner allowing it to fit within the side opening in the well;
• a first end portion of the insertion device comprises a bending head with a bending path, wherein the bending head is structured in a manner allowing it to directionally deviate the coiled tubing upon conducting the coiled tubing along the bending path;
• the insertion device is provided with a guide conduit extending from a second end portion of the insertion device and onwards to the bending head for allowing the coiled tubing to be conducted into the bending head.
• this injection module comprises its own insertion device with an associated bending head for a coiled tubing
• the injection module distinguishes significantly from the technical solutions according to the above-mentioned US 5.927.405 and US 6.186.239.
• both of these publications concern lateral insertion of a flexible hose, not a coiled tubing, into an annulus in a well.
• the insertion of the hose is carried out via a hose bending device in the form of a downwardly bent passage formed in the sidewall of a wellhead, or in the form of a downwardly bent passage formed in a guide bushing screwed into a straight side opening in the wellhead.
• the wellhead must be specially adapted in advance with such a bending device to allow the hose to be conducted into the annulus of the well.
• the latter is not required when using the present injection module for lateral insertion of a coiled tubing in a well.
• side openings and/or pipe stubs being insignificantly adapted or not adapted for this purpose, may be used, for example a standard side bore in a wellhead or similar.
• said injection equipment for coiled tubing operations may typically comprise a suitable blowout preventer ("BOP"), stuffing box or stripper, a lubricator with suitable sealing elements, at least one shear ram, various associated fittings and a conveyor device for coiled tubing .
• BOP blowout preventer
• stuffing box or stripper stuffing box or stripper
• lubricator with suitable sealing elements at least one shear ram
• various associated fittings and a conveyor device for coiled tubing .
• An injection apparatus with a heavy duty, chain-based conveyor device is described, for example, in US 5.188.174.
• the conveyor device is also used for withdrawing the coiled tubing when required.
• Such injection equipment constitutes prior art and will not be discussed in further detail herein.
• the coiled tubing to be conducted into the well via said side opening must have an outer dimension fitting into the particular cavity in the well, for example in a production tubing, in an annulus between two sizes of casing, or in an annulus between a formation wall and a casing.
• the coiled tubing must have a relatively small outer diameter for allowing it to fit into the annulus.
• such a coiled tubing will be coiled upon a spool or reel for spooling in or out therefrom. Even though the spool or reel may be connected to the injection module, the spool/reel will typically be present as a separate unit which must be connected to the injection module.
• the coiled tubing may also be connected to pumping equipment for introduction of a fluid in the well, for example a fluidized treatment agent.
• this fluid may be comprised of, for example, a well killing fluid, including a high density liquid, or of cement, a sealing agent or another, suitable well treatment agent.
• a well killing fluid including a high density liquid, or of cement, a sealing agent or another, suitable well treatment agent.
• the coiled tubing is pushed (injected) into the well via the insertion device so as to become directionally deviated along the bending path in said bending head.
• the nose portion (front end) of the coiled tubing may be directionally deviated before or after having connected the injection module to the side opening of the well . If the directional deviation is carried out before connecting the injection module to the side opening, the nose portion of the coiled tubing will be prepared for further insertion in the well once the injection module is connected to the side opening . This renders possible to quickly initiate the continued insertion of the coiled tubing in the well.
• the coiled tubing may discharge from the bending head in a direction substantially parallel to the particular well pipe or annulus.
• the coiled tubing is injected into .the well by means of the conveyor device of the injection module, the device of which the coiled tubing must be connected to first before initiating the injection.
• the nose portion of the coiled tubing may be provided with an insertion head or similar device which is rounded or chamfered in order to facilitate the insertion of the coiled tubing.
• an insertion head is shown in said US 5.927.405.
• the present injection module may also be structured for releasable connection to said side opening.
• the injection module may be used as a transportable unit capable of being moved from well to well, as required.
• the insertion device of the injection module may also be connected to a moving means disposed on the injection module;
• the moving means is structured in a manner allowing it to move the insertion device relative to the injection module after the connection thereof to the side opening in the well.
• this moving means may comprise a movable piston.
• This piston may mechanically, hydraulically, pneumatically or electrically operated and possible be disposed in an associated piston cylinder.
• the moving means may comprise at least one pitch rack guide, for example in the form of a rotatable, toothed bar/rack connected to a toothed pinion/gear, motor or similar driving device for rotation of the toothed bar/rack.
• the insertion device may be thread-connected to the toothed bar/rack. Thereby, the insertion device will be able to move in the desired direction through suitable rotation of the toothed bar/rack.
• the insertion device of the injection module may be cylinder-shaped or sleeve-shaped for allowing it to fit within a circular side opening in the well, for example a side bore in a wellhead.
• a side bore will be connected to a horizontal pipe stub, the free end of which is provided with a coupling flange.
• the pipe stub may also comprise at least one valve, for example a gate valve, and at least one measuring instrument, for example a pressure gauge.
• said guide conduit in the insertion device may be comprised of a bore formed in the insertion device.
• the bendi ng path of the insertion device may be formed through casting of the bending head .
• the bending head must be formed from a suitable casting material capable of enduring the loads inflicted by the coiled tubing on the bending head during the movement of the coiled tubing along the bending path.
• the bending head may thus be formed from from cast iron or some other metallic material, or an alloy of cast i ron and some other metallic material, or from composite materials.
• the resulting bending path may also be given a finishing treatment for obtaining a hard-wearing surface, for example by means of a hardfacing.
• the bending head may comprise at least two cooperating profile parts having complementarily shaped contact surfaces collectively defining the bending path .
• Such profile parts may be cast or machined into the respective, complementary shape.
• the profile parts must also be able to endure the loads inflicted by the coiled tubing on the profile parts during the movement of the coiled tubing along the bending path between the profile parts.
• the profile parts may be formed from the same materials mentioned in the preceding example, and said contact surfaces may possibly be given a finishing treatment for obtaini ng hard- wearing surfaces, for example by means of hardfacings.
• the bending head may comprise at least two cooperating wheels collectively defining at least a portion of the bending path, wherein the cooperating wheels are structured in a manner allowing them to directionally deviate the coiled tubing along the bending path upon conducting the coiled tubing between the wheels.
• the bending head may comprise one or more sets of cooperating wheels bending and guiding the coiled tubing along the bending path.
• the wheels must be able to endure the loads inflicted by the coiled tubing on the wheels during the movement of the coiled tubing along the bending path between the wheels.
• the wheels may be formed from steel or composite materials and, at the circumferences thereof, the wheels may possibly be given a finishing treatment for obtaining hard-wearing surfaces, for example by means of hardfacings.
• the insertion device may comprise a directional stabilizer disposed at an outlet from the bending head for directional control of the coiled tubing after the outlet.
• the purpose of such a directional stabilizer is to function as a counteracting impact surface against which the discharging coiled tubing impinges and hence is straightened out after the coiled tubing has been bent inside the bending head.
• the directional stabilizer may be comprised of at least one guiding device or similar, for example a guide rail, a guiding groove, a guide edge, a guide plate or a guide block, which guides guides the coiled tubing in the correct downward direction for the continued insertion in the well.
• a directional stabilizer does not constitute a prerequisite for allowing the coiled tubing to be conducted onwards into the well. Without such a directional stabilizer, the coiled tubing may impinge on a pipe wall, whereby the pipe wall will function as a counteracting and directionally controlling impact surface for the coiled tubing .
• the impact force inflicted by the coiled tubing on the directional stabilizer or a pipe wall will also be dependent on the degree of bending of the coiled tubing when being conducted through said bending head.
• the insertion device may be provided with a return flow conduit for potential return flow of a fluid from the well.
• a fluid volume displaced by the fluid being pum ped down into the well via the coiled tubing may flow out of the well via said return flow conduit.
• the bending path of the insertion device may be structured in a manner allowing it to directionally deviate the coiled tubing by approximately 90 degrees, i.e. to directionally deviate the coiled tubing approximately perpendicular relative to the direction of the coiled tubing before being conducted through the bending head.
• the bending path of the insertion device may be structured in a manner allowing it to directionally deviate the coiled tubing by less than 90 degrees, for example in the region of 20-80 degrees relative to the direction of the coiled tubing before being conducted through the bending head.
• the well may thus be provided with such a non-horizontal side opening and/or pipe stub, for example in connection with a wellhead.
• a non-horizontal side opening and/or pipe stub for example in connection with a wellhead.
• this may be carried out by virtue of the very injection module being structured in a manner allowing it to be positioned obliquely relative to the base thereof, or by virtue of the injection module's injection equipment, including said conveyor device, being disposed in an oblique position relative to the base.
• a method for lateral insertion and bending of a coiled tubing via a side opening in a well comprises the following steps:
• the nose portion of the coiled tubing may be directionally deviated before or after connecting the injection module to the side opening of the well, as mentioned above.
• the injection module may be releasable connected to said side opening. By so doing, the injection module may be moved from well to well, as required.
• the coiled tubing may be conducted into an annulus in the well, for example in an annulus between two sizes of casing, or in an annulus between a formation wall and a casing.
• the coiled tubing may be conducted into a well pipe in the well, for example a production tubing.
• the method may also comprise a step (E) of conducting a fluid, for example a fluidized treatment agent, through the coiled tubing and onwards to the " desired location in the well .
• this location may be located in vicinity of a leaking packer or cement in an annulus or casing in the well.
• the fluid may be comprised of a well killing fluid, for example drilling mud, or of cement or of a sealing agent.
• At least one annulus and/or well pipe in a well to be plugged and abandoned may be filled fully or partly in advance with at least one suitable fluid, for example cement and/or a fluidized sealing material.
• at least one suitable fluid for example cement and/or a fluidized sealing material.
• a coiled tubing for injection of fluids or fluidized materials in an underground formation.
• the coiled tubing may be used to i nject water and/or gas in a permeable formation in order to maintain the pressure in the formation and hence the production of fluids from the formation.
• the coiled tubing for injection of fluidized waste materials, for example fluidized drill cutting or similar, in an underground formation .
• a potential return flow of a fluid from the well may be conducted out via a separate outlet opening in the well, for example a side outlet in a wellhead.
• This outlet opening is separate from said side opening for connection of the injection module.
• the method may comprise the following :
• step (A) using an insertion device comprising a return How conduit;
• step (E) allowing a return flow of a fluid from the well to flow out via the return flow conduit.
• the fluid displaced by the fluid being pumped down into the well via the coiled tubing may flow out of the well via said return flow conduit.
• the method may also comprise the following :
• step (A) using an insertion device comprising a bending path structured in a manner allowing it to bend the coiled tubing by approximately 90 degrees;
• step (C) conducting the coiled tubing through the bending path so as to directionaliy deviate the coiled tubing by approximately 90 degrees.
• the method may comprise the following :
• step (A) using an insertion device comprising a bending path structured in a manner allowing it to bend the coiled tubing by less than 90 degrees;
• step (C) conducting the coiled tubing through the bending path so as to directionaliy deviate the coiled tubing by less than 90 degrees.
• the coiled tubing is directionaliy deviated by less than 90 degrees, fo example in the region of 20-80 degrees relative to the direction of the coiled tubing before being conducted through the bending head.
• the method may also comprise the following :
• step (A) connecting the insertion device to a moving means disposed on the injection module;
• step (B) after having connected the injection module to the side opening of the well, conducting the insertion device into said side opening by means of the moving means.
• the method may also comprise the following ;
• step (D) separating the coiled tubing from the injection module
• Such a solution may be advantageous if it is desirable to fixedly mount a coiled tubing in the well, for example -in an annulus thereof. By so doing, the well is prepared for future well operations. For example, it may concern introduction of a pressure- remedying fluid should a potential pressure build-up occur in the well.
• a fixedly mounted coiled tubing may be used for gas lift purposes, for water injection or for injection of waste materials into an underground formation.
• a third aspect of the invention concerns use of an injection module according to the above-mentioned, first aspect of the invention for lateral insertion and bending of a coiled tubing via a side opening in a well.
• Figure 1 shows a side perspective of an injection module according to the invention connected to a coiled tubing extending from a separate coiled tubing spool;
• Figures 2-6 illustrate, in various perspectives, how the injection module is connected to a side bore in a wellhead, and how a cylinder-shaped insertion device of the injection module then is conducted into the side bore, the insertion device being provided with a first embodiment of a bending head;
• Figure 7 shows, partially in section, a side perspective of the injection module and the insertion device according to figures 2-6 whilst said coiled tubing is being conducted into an annulus in the wellhead via the insertion device;
• Figure 8 shows, in larger scale, a section through the insertion device and the wellhead shown in figure 7;
• Figure 9 shows, partially in section, a side perspective of a second embodiment of a bending head for the insertion device according to the invention.
• Figure 10 shows, in smaller scale and in a partially exploded view, a side perspective of the bending head according to figure 9 whilst said coiled tubing is being conducted into an annulus in the wellhead via this bending head for the insertion device;
• Figures 11-17 show in sections and in partially exploded views, among other things, various perspectives of a third embodiment of a bending head for the insertion device according to the invention.
• Figures 1-7 show an injection module 2 according to the invention connected to a thin coiled tubing 4 coiled upon a separate coiled tubing spool 6 placed in immediate vicinity of the injection module 2.
• the spool 6 and the coiled tubing 4 may also be connected to a line (not shown) for allowing, at a later point in time, pu mping of a treatment agent, for example a well killing fluid, via the coiled tubing 4 and into an underground well.
• the injection module 2 and the coiled tubing spool 6 are placed beside a wellhead 8 on a wellhead deck 10 on an offshore platform .
• the injection module 2 and the coiled tubing spool 6 may just as well be placed beside a wellhead on a land-based well.
• the injection module 2 comprises a frame structure 12 provided, among other things, with various injection equipment for coiled tubing operations.
• this injection equipment in this embodiment comprise a heavy duty conveyor device 14 for the coiled tubing 4; a shear ram 16 connected to a respective inlet 18 and outlet 20 for hydraulic fluid for activation of the shear ram 16; and a stuffing box 22 connected to a flexible return hose 24.
• the stuffing box 22 contains at least one packer element which, by means of an associated piston device, is forced in a pressure-sealing manner around the coiled tubing 4 when being conducted through the stuffing box 22.
• Such injection equipment constitute prior art.
• FIG. 14 An example of a conveyor device resembling the present conveyor device 14, is described in detail in the above-mentioned US 5.188.174.
• the stuffing box 22 Seen further in the insertion direction of the coiled tubing 4, the stuffing box 22 is connected in a pressure-sealing manner to an insertion device according to the invention.
• figures 1-7 show a lengthy and cylinder-shaped insertion device 26 through which the coiled tubing 4 may be conducted, as required.
• said conveyor device 14 contains two parallel and endless chains 28, 30, each of which is disposed in a rotatable manner around a respective set of chain sprocket wheels (not shown). Nearby and opposite sides of the chains 28, 30 are also arranged with some distance therebetween so as to allow them, when in their positions of use, to conduct the coiled tubing 4 between the opposite chain sides.
• each chain 28, 30 is provided with continuous, external gripping elements (nto shown) which, when in their positions of use, are forced against the coiled tubing 4 so as to grip it simultaneously with the chains 28, 30 rotating synchronously for conveyance of the coiled tubing 4.
• Driving devices and associated equipment for the purpose of forcing said gripping elements towards the coiled tubing 4, and for the purpose of rotating said chain sprocket wheels and thus the chains 28, 30, are not shown in the figures.
• driving devices may be comprised of rotary motors and hydraulic cylinders with associated pistons.
• the coiled tubing 4 may be conducted onwards through the shear ram 16, the stuffing box 22 and into the insertion device 26, which will be explained in further detail in the following.
• the conveyor device 14, the shear ram 16, the stuffing box 22 and the insertion device 26 are assembled in a coaxial manner for conducting the coiled tubing 4 along a mutual axis.
• said insertion device 26 comprises a first end portion 32 comprised of a cast bending head 34 according to a first embodiment thereof.
• a bending path 36 is formed within the bending head 34 during the casting thereof.
• the bending head 34 is structured in a manner allowing it to directionally deviate the coiled tubing 4 by ca. 90 degrees when conducted along the bending path 36.
• the insertion device 26 is also provided with a guide conduit in the form of a first bore 38 extending from a second end portion 40 of the insertion device 26 and onwards to the bending head 34. Thereby, the coiled tubing 4 may be conducted forward and be pushed into the bending head 34 by means of the conveyor device 14.
• the insertion device 26 is provided with a return flow conduit in the form of a second bore 42 extending between the first and second end portions 32, 40 of the insertion device 26.
• the guide conduit 38 and the return flow conduit 42 are shown best in figure 6.
• both the injection equipment for coiled tubing operations and the insertion device 26 are structured so as to be horizontally movable relative to the frame structure 12.
• the frame structure 12 is provided with a moving means comprising, among other things, two parallel and horizontal thread bars, i.e. a first thread bar 44 and a second thread bar 46, which are disposed at a distance from each other.
• the thread bars 44, 46 have threads of a self- locking type.
• suitable bearings (not shown in the figures), the ends of the thread bars 44, 46 are supported in rotatable manner in respective sides of a first support plate 48 (closest to the spool 6) and a second support plate 50 (closest to the wellhead 8), respectively.
• the su pport plates 48, 50 are secured at either end of the frame structure 12.
• the thread bars 44, 46 are connected to at least one driving device (not shown), for example an electric or hydraulic rotary motor.
• the second support plate 50 is also provided with a respective centre hole 52 through which the insertion device 26 is conducted during use.
• the second support plate 50 is provided with a ring-shaped connector 54 disposed on the outside of the support plate 50 and around the centre hole 52 thereof.
• the connector 54 is used for pressure-tight connection of the injection module 2 to a coupling flange 56 on a horizontal pipe stub 58 provided with a pressure gauge 60 and a gate valve 62, and which is connected to a side bore 64 on the wellhead 8.
• the side bore 64 communicates with an annulus 66 between two sizes of casing, i .e. a first casing 68 and a second casing 70, in the wellhead 8.
• the moving means of the frame structure 12 also comprises a first, second and third moving plate 72, 74, 76 movably connected to the thread bars 44, 46 via
• corresponding th readed holes 78 also having self-locking threads, and which are disposed in respective sides of of each moving plate 72, 74, 76.
• the conveyor device 14 is attached between the first and second moving plate 72, 74, whereas the shear ram 16 and the stuffing box 22 are attached to the second and third moving plate 74, 76.
• These equipment components 14, 16, 22 with associated equipment are also disposed between the thread bars 44, 46. Upon appropriate rotatition of the thread bars 44, 46, these equipment components with associated equipment will therefore move horizontally relative to the frame structure 12, which is placed on the wellhead deck 10.
• the separate injection module 2 is connected to said horizontal pipe stub 58 on the wellhead 8, after which it is possible to carry out a lateral insertion and bending of the coiled tubing 4 via said side bore 64 in the wellhead 8.
• This connection is carried out by connecting, in a pressure-sealing manner, said connector 54 on the injection module 2 to the coupling flange 56 on the pipe stub 58, as shown in figures 2 and 3.
• the gate valve 62 on the pipe stub 58 will be closed .
• the gate valve 62 is opened, after which the insertion device 26 is conducted through the centre hole 52 in the connector 54 and onwards through the pipe stub 58 and the side bore 64 until the bending head 34 is placed in the annulus 66 of the wellhead 8, as shown in figures 4-6.
• the shear ram 16 and the conveyor device 14 in the direction of the wellhead 8 is carried out through appropriate rotation of the thread bars 44, 46 of the injection module 2, as explained above.
• the endless chains 28, 30 of the conveyor device 14 are activated and pushed the coiled tubing 4, which in advance has been conducted into the equipment components 14, 16, 22 and through the first bore 38 (the guide conduit) of the insertion device 26 and onwards via the bending path 36 of the bending head 34.
• the nose portion of the coiled tubing 4 has been prepared in advance for continued insertion in the annulus 66 once the injection module 2 has been connected to the side bore 64 in the wellhead 8.
• the coiled tubing 4 is directionally deviated by ca.
• a suitable fluid for example a heavier well killing fluid, may be pumped through the coiled tubing 4 and down to this location in the annulus 66.
• the fluid already located in the annulus 66, and which is displaced by the fluid being pumped down into the annulus 66 via the coiled tubing 4, may flow out of this upper portion of the annulus 66 via said second bore 42 (the return flow conduit) in the insertion device 26.
• the coiled tubing 4 may be withdrawn from the annulus 66.
• the coiled tubing 4 may possibly be separated from the injection module 2. Then the separated coiled tubing 4 is connected to the side bore 64 of the wellhead 8. By so doing, the coiled tubing 4 is fixedly installed in the annulus 66 and is prepared for future well operations.
• FIGS. 9 and 10 show a cylinder-shaped bending head 34' according to a second embodiment thereof.
• This bending head 34' is disposed at the first end portion 32 of the insertion device 26 and is hydraulically connected to the second end portion 40 of the insertion device 26, for example via a lengthy connector. Even though this bending head 34' is not provided with a return flow conduit, which is contrary to the preceding bending head 34, also the bending head 34' may be provided with such a return flow conduit.
• This bending head 34' comprises two cooperating profile parts, i.e. a first profile part 80 and a second profile part 82.
• the profile parts 80, 82 have complementarily shaped contact surfaces, i.e. a first contact surface 84 and a second contact surface 86, collectively defining a bending path 36' structured in a manner allowing it to directionally deviate the coiled tubing 4 by ca. 90 degrees.
• the first profile part 80 is comprised of a massive, circular cylinder provided with an external groove (only shown in part), the innermost part of which has a shape forming the first contact surface 84 defining one surface portion of the bending path 36'.
• This groove also comprises a longitudinal groove portion 84' on the upper side of the profile part 80, and a transverse groove portion 84" at the outer end of the profile part 80. Viewed in cross-section, the contact surface 84 forms a partial circle.
• the second profile part 82 is comprised of a slender angle profile fitting into said groove in the first profile part 80, and which internally has a shape forming the second contact surface 86. A mid-portion of this contact surface 86 defines the remaining, opposite surface portion of the bending path 36'.
• the inside of the angle profile 82 also comprises a longitudinal groove portion 86' and a transverse groove portion 86". Viewed in cross-section, the second contact surface 86 forms a partial circle fitting in a complementary manner together with the first contact surface 84 so as to collectively define the bending path 36'.
• the second profile part 82 is also formed with a longitudinal, arcuate strip 88 with peripheral, outwardly-directed flanks 90 fitting into corresponding recesses (not shown) in the external groove in the first profile part 80.
• the strip 88 and its flanks 90 will complement the external, circular shape of the first profile part 80.
• the bending head 34' may be readily conducted into said annulus 66 via the pipe stub 58 of the wellhead 8, as shown in figure 10.
• FIG. 11-17 show a cylinder-shaped bending head 34" according to a third embodiment thereof. Also this bending head 34" is disposed at the first end portion 32 of the insertion device 26 and is hydraulically connected to the second end portion 40 of the insertion device 26, for example via a lengthy connector.
• the bending head 34" comprises, among other things, a front end within which a bending path 36" is formed. Also this bending path 36" is structured in a manner allowing it to directionally deviate the coiled tubing 4 by ca. 90 degrees.
• the bending head 34" also comprises a straight portion provided with a bore 92 (guide conduit) for the coiled tubing 4 and a hydraulics bore 94; cf. figures
• the bore 92 continues onwards to the bending path 36", whereas the hydraulics bore 94 continues onwards to a movable piston 96 disposed in hydraulic cylinder 98.
• the piston 96 is connected to a piston rod 100 conducted through a hole in a partition wall 102, and which is connected to a lengthy directional stabilizer 104 disposed directly at an outlet 106 from the bending head 34".
• a lengthy directional stabilizer 104 disposed directly at an outlet 106 from the bending head 34.
• the supportive force exerted by the directional stabilizer 104 on the coiled tubing 4 in this context, may be adjusted by means of the piston 96 and the hydraulic pressure supplied via the hydraulics bore 94.
• the bending head 34" also comprises a wheel frame 110 provided with two
• cooperating and rotatable wheels i.e. a first wheel 112 and a somewhat larger, second wheel 114, and a transverse bolt 116 suspended in the wheel frame 110 at an outer end thereof.
• the wheels 112, 114 have complementarily shaped circumferences which, when assembled vis-a-vis each other, defines a lower portion of the bending path 36". Viewed in cross-section, each opposite wheel circumference thus forms a partial circle.
• the wheels 112, 114 are disposed with some distance therebetween so as to allow them to conduct the coiled tubing 4 therebetween, as shown in figure 13.
• the first wheel 112 is rotatably arranged via a needle bearing 118 attached around a transverse axle 120 supported in two first holes 122 in the wheel frame 110.
• the second wheel 114 is rotatably arranged via a needle bearing 124 attached around a transverse axle 126 carried through two second holes 128 in the wheel frame 110 (cf. figures 11, 15 and 17), and which are supported in two holes 130 in the very bending head 34" (cf.
• the first wheel 112 may be rotated somewhat around the transverse axle 126 attached to the very bending head 34".
• this construction may be used to adjust the pressure force exerted by the first wheel 112 on the coiled tubing 4 when being conducted through the bending path 36".
• said transverse bolt 116 at the outer end of the wheel frame 110 is provided with a threaded hole 132 through which a threaded bolt 134 is screwed .
• the threaded bolt 134 is carried through a passage 136 in the front and upper end of the bending head 34". This passage 136 continues up to a shoulder 138 in a recess 140 at the top of the bending head 34".
• a bolt head 142 of the threaded bolt 134 is supported on this shoulder 138.
• the first wheel 112 may be rotated in the desired direction around the transverse axel 126 supported in the bending head 34".
• the first wheel 112 may be raised or lowered relative to the coiled tubing 4 when conducted between the wheels 112 and 114, as shown in figure 13.
• said pressure force on the coiled tubing 4 may be adjusted suitably. The pressure force on the coiled tubing 4 will increase when the first wheel 112 is lowered, whereas the pressure force will be reduced upon raising the wheel 112.
• This raising- and lowering function of the first wheel 112 may also be achieved by connecting the transverse bolt 116 in the wheel frame 110 to a piston (not shown) connected to a hydraulic, pneumatic or electric driving device (not shown) placed in the bending head 34".
• a driving device may possibly be structured for remote activation and control.
• the bending head 34" may also be provided with various meters, electronics, etc. for feedback and control of the driving device and the position of the first wheel 112 in the bending head 34" and with respect to the coiled tubing 4.
• a return flow of a fluid from the annulus 66 may be conducted via a potential return flow conduit (not shown) arranged in the bending head 34" between the bore 92 for the coiled tubing 4 and the hydraulics bore 94.
• a return flow conduit may also be in flow communication with a corresponding return flow conduit arranged in the remaining part of the insertion device 26.

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• Engineering & Computer Science (AREA)
• Geology (AREA)
• Mining & Mineral Resources (AREA)
• Life Sciences & Earth Sciences (AREA)
• General Life Sciences & Earth Sciences (AREA)
• Fluid Mechanics (AREA)
• Environmental & Geological Engineering (AREA)
• Physics & Mathematics (AREA)
• Geochemistry & Mineralogy (AREA)
• Mechanical Engineering (AREA)
• Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
• Bending Of Plates, Rods, And Pipes (AREA)
• Earth Drilling (AREA)
• Guides For Winding Or Rewinding, Or Guides For Filamentary Materials (AREA)
• Shaping Of Tube Ends By Bending Or Straightening (AREA)
• Rigid Pipes And Flexible Pipes (AREA)
• Infusion, Injection, And Reservoir Apparatuses (AREA)
• Working Measures On Existing Buildindgs (AREA)
• Magnetic Resonance Imaging Apparatus (AREA)

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• 2009
  • 2009-12-07 NO NO20093484A patent/NO332472B1/no unknown
• 2010
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  • 2010-12-06 WO PCT/NO2010/000447 patent/WO2011071389A1/en active Application Filing
  • 2010-12-06 DK DK10836257.5T patent/DK2510185T3/en active
  • 2010-12-06 EP EP10836257.5A patent/EP2510185B1/en active Active
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