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WO1995009967A1 - Appareil et procede declenches au fond d'un forage, pour le conditionnement d'un puits de forage - Google Patents

Appareil et procede declenches au fond d'un forage, pour le conditionnement d'un puits de forage Download PDF

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Publication number
WO1995009967A1
WO1995009967A1 PCT/US1993/009688 US9309688W WO9509967A1 WO 1995009967 A1 WO1995009967 A1 WO 1995009967A1 US 9309688 W US9309688 W US 9309688W WO 9509967 A1 WO9509967 A1 WO 9509967A1
Authority
WO
WIPO (PCT)
Prior art keywords
casing pipe
casing
string
pipe string
borehole
Prior art date
Application number
PCT/US1993/009688
Other languages
English (en)
Inventor
Wilber R. Moyer
Larry K. Moran
Dennis R. Wilson
Original Assignee
Conoco Inc.
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 Conoco Inc. filed Critical Conoco Inc.
Priority to PCT/US1993/009688 priority Critical patent/WO1995009967A1/fr
Publication of WO1995009967A1 publication Critical patent/WO1995009967A1/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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1014—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/11—Perforators; Permeators
    • E21B43/116—Gun or shaped-charge perforators
    • E21B43/117—Shaped-charge perforators
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/11—Perforators; Permeators
    • E21B43/116—Gun or shaped-charge perforators
    • E21B43/1185—Ignition systems

Definitions

  • This invention relates to completing a well traversing earth formation in a borehole and more particularly to completing the well by means of flow path devices positioned on a casing string and also by completing the wellbore in an underbalanced pressure condition by means of explosive devices located on the casing string.
  • the well In the process of establishing an oil or gas well, the well is typically provided with an arrangement for selectively excluding fluid communication with certain zones in the formation to avoid communication with undesirable fluids.
  • a typical method of controlling the zones with which the well is in fluid communication is by running well casing down into the well and then sealing the annulus between the exterior of the casing and the walls of the wellbore with cement. Thereafter, the well casing and cement may be perforated at preselected locations by a perforating device or the like to establish a plurality of fluid flow paths between the pipe and the product bearing zones in the formation.
  • the charges are placed in extendable pistons mounted in a casing string and a pressure wave producing device is run into the casing string in a separate operation.
  • the casing may also then be cemented before the charges are detonated.
  • the charges are directed into the formation without passing through the casing and/or cement.
  • the system comprises a piston for being mounted in an opening in the peripheral wall of the pipe and for extending generally radially outwardly from the pipe to contact the wall of the wellbore wherein the piston includes an explosive device therein.
  • a deploying device deploys the piston from a retracted position which is generally within the maximum exterior profile of the pipe to an extended position wherein the piston extends generally radially from the opening to contact the wall of the wellbore.
  • a detonation device is then positioned in the wellbore for detonating the explosive device in the piston while the piston is in its deployed position against the wall of the formation so as to perforate the formation by an explosive proximate to the formation.
  • the piston when extended serves to center the pipe in the borehole and is substantially clear of the inner bore of the pipe to render the bore of the pipe full open.
  • the system may include a tubing string installed within the casing pipe wherein the bore of the casing pipe is placed in an underbalanced pressure condition prior to opening the flow path devices.
  • the tubing string may be provided with a packer or the like to close off the annular space between the tubing string and the casing.
  • Figure 1 is a cross-sectional view of a wellbore traversing earth formations with a casing string arranged therein and spaced from the walls of the wellbore by a plurality of downhole activated pistons which are shown being activated to an extended position and which embody features of the present invention.
  • Figure 2 is an enlarged cross-sectional end view of the casing taking along lines 2-2 in Figure 1, wherein the centralizers are shown extended to center the casing string in the wellbore.
  • Figure 3 is a cross-sectional end view similar to
  • Figure 4 is an enlarged cross-sectional view of a centralizer piston having a detonation device and shaped charge positioned therein, with the piston shown in a retracted or running-in position relative to the casing wall.
  • Figure 5 is an enlarged cross-sectional view of the centralizer piston of Figure 4 in an extended position wherein the outer end of the piston is in contact with an earth formation.
  • Figure 6 is a cross-sectional view of a wellbore showing a casing centralized in a borehole by pistons in an extended position and further showing a pressure wave generating device positioned in the casing by means of a tubing string.
  • a wellbore W is shown having been drilled into the earth formations such as for the exploration and production of oil and gas.
  • the illustrated wellbore W includes a generally vertical section A, a radial section B leading to a horizontal section C.
  • the wellbore has penetrated several formations, one of which may be a hydrocarbon- bearing zone F.
  • the wellbore W was drilled to include a horizontal section C which has a long span of contact with the formation F of interest, which may be a hydrocarbon-bearing zone. With a long span of contact within a pay zone, it is likely that more of the hydrocarbon present will be produced.
  • there are adjacent zones which have fluids such as brine that may get into the production stream and thereafter have to be separated from the hydrocarbon fluids and disposed of at additional costs. Accordingly, fluid communication with such adjacent zones is preferably avoided.
  • wellbores are typically cased and cemented and thereafter perforated along the pay zones.
  • the casing tends to lay against the bottom wall of the wellbore, thereby preventing cement from encircling the casing and leaving a void for wellbore fluids such as brine to travel along the wellbore and enter the casing far from the formation from which it is produced.
  • a casing string or liner 60 has been run therein which is spaced from the walls of the wellbore by a plurality of downhole activated pistons generally indicated by the number 50, which serve to centralize the casing.
  • the downhole activated pistons or centralizers 50 are retracted into the casing 60 while it is being run into the wellbore as is illustrated by the centralizers 50 in Figure 1 which are ahead of an activator or pusher 82.
  • the centralizers 50 are deployed to project outwardly from the casing as illustrated behind the activator or in Figure 1.
  • the centralizers 50 move the casing from the walls of the wellbore if the casing 60 is laying against the wall or if the casing is within a predetermined proximity to the wall of the wellbore W. This movement away from the walls of the wellbore will thereby establish an annular free space around the casing 60.
  • the centralizers 50 maintain the spacing between the casing 60 and the walls of the wellbore W while cement is injected into the annular free space to set the casing 60.
  • the pistons are latched in an extended position and will thereby maintain the casing 60 centered even if the casing is not cemented.
  • the centralizers 50 are better illustrated in
  • FIGs 2 and 3 wherein they are shown in the extended and retracted positions, respectively.
  • seven centralizers 50 are illustrated for supporting the casing 60 away from the walls of the wellbore W although only four are actually shown contacting the walls of the wellbore W. It should be recognized and understood that the centralizers work in a cooperative effort to centralize the casing 60 in the wellbore W.
  • the placement of the centralizers 50 in the casing 60 may be arranged in any of a great variety of arrangements. Applicants' related U.S. Patent No. 5,228,518 which is incorporated herein by reference describes these arrangements in greater detail.
  • the 7 illustrated centralizers 50 are evenly spaced around the casing 60.
  • annular space 70 is created around the casing within the wellbore.
  • the casing 60 is run into the wellbore with the centralizers 50 retracted as illustrated in Figure 3 which allows substantial clearance around the casing 60 and permit the casing 60 to follow the bends and turns of the wellbore W. Such bends and turns particularly arise in a highly deviated or horizontal hole.
  • the centralizers 50 With the centralizers 50 retracted, the casing 60 may be rotated and reciprocated to work it into a suitable position within the wellbore.
  • the slim dimension of the casing 60 with the centralizers 50 retracted ( Figure 3) may allow it to be run into wellbores that have a narrow dimension or that have narrow fittings or other restrictions.
  • the centralizers 50 may present small bulbous portions 80 on the outside of the casing 60. It is preferable not to have any dimension projecting out from the casing to minimize drag and potential hangups while moving the string.
  • the bulbous portions 80 are utilized in some embodiments especially in smaller diameter casings such is often used in horizontal holes when they are cased.
  • the bulbous portions 80 are rounded to slide better along the walls of the wellbore and that the casing string 60 will include collar sections 90 that will extend out radially farther than the bulbous portion (see Figure 3) .
  • the collar sections 90 present the maximum outer profile of the casing string even when the bulbous portions are present.
  • the outward projection of the retracted centralizers 50 being within the maximum outer profile of the casing string 60 is believed to minimize any problems of running the casing.
  • a deploying device or pusher 82 which moves from the top of the casing to its bottom end is shown positioned within the horizontal curved section B of the casing string.
  • the deploying device 82 is sized to push the pistons 50 from a retracted to an extended position. It is noted that the centralizers or pistons 50 behind or to the left of the pusher 82 are in an extended position having been engaged by the tapered nose portion 85 of the pusher.
  • the tapered portion 85 engages the inner ends of the pistons and pushes them outwardly as the piston travels until the body portion 83 has passed the piston whereupon the piston will be fully extended and locked into an extended position as will be hereinafter described.
  • the centralizers in front of the pusher 82 are still in a retracted position and consequently the horizontal portion C of the casing in front of the pusher is shown lying on the bottom side of the borehole.
  • the upper vertical section A and radial section B are shown centered in that the pistons 50 have been deployed to an extended position.
  • the activator device shown in Figure 1 is a pumpable activator or deploying device having a tail pipe 81 which extends rearwardly from the main body portion 83 and seals the rear end of the device to the inside of the casing so that the device may be pushed down through the casing 60 by the application of hydraulic pressure.
  • the activator may be run into the casing string on the end of a pipe string such as a drill pipe or coiled tubing wherein force is applied to the pipe string and thus to an activation device to engage and push out or extend the pistons 50.
  • the centralizers or pistons may take many forms and shapes as is also described in Patent No. 5,246,861.
  • the piston or centralizer 50 is shown in Figures 4 and 5 as including an explosive charge for perforating formations in the borehole.
  • the centralizer 50 has a cylindrical or substantially cylindrical barrel portion or piston 12 which is slidably received in a bore in button 14.
  • the button 14 is threadedly received within a tapped hole 16 which extends transversely through the wall of casing 60.
  • a bulbous or rounded outer portion 80 extends outwardly slightly beyond the outside wall of the casing 60 but only to provide an adequate seat for the button 14 in thin wall smaller diameter casing and is constructed so that the outer extension of the bulbous portion 80 does not exceed the maximum profile of the pipe string which would normally be represented by the outside diameter of collars 90 in the casing string.
  • the button 14 has a shoulder 17 formed at the base of the bulbous outer portion 80 that provides a surface for seating within a mating recessed surface at the outer end of the threaded hole 16 in the casing wall.
  • the shoulder 17 forms a vertical surface on the button which fits against the mating vertical surface at the outer end of hole 16.
  • An 0-ring 18 is arranged within a groove on the shoulder 17 to provide a seal between the shoulder 17 and a vertical face at the end of hole 16.
  • the button 14 is arranged so that its inner end does not extend into the interior of the casing 60.
  • the piston 12 is arranged for axial movement through the button 14 from a retracted position ( Figures 3 and 4) to an extended position ( Figures 2 and 5) .
  • the piston 12 and the button 14 are mounted into casing 60 so that their, axis are collinear and directed radially outwardly with respect to the axis of the casing 60.
  • the piston 12 includes a plug 19 secured in an interior bore or passageway 18 in the piston by screw threads 22.
  • An annular sealing ring 21 is positioned between the plug 19 and the inner end of piston 12.
  • the piston 12 shown in Figures 4 and 5 also serves as a housing for a perforating device.
  • the plug 19 is called an initiator plug in that it carries a device for initiating detonation of a shaped charge in the piston.
  • the plug 19 does not fill the entire passageway 18 but is rather approximately the thickness of the casing 60.
  • the plug 19 further includes a rounded inner end face 25 and a flat distal end face 24. The rounded surface 25 on the inner end of plug 19 is provided for facilitating the use of a deploying device to push the centralizer 50 into an extended position.
  • the distal end 28 of the piston 12 may be chamfered or tapered inwardly to ease the installation of the piston 12 into the button 14.
  • the piston 12 is mounted in a central bore in the button 14 which is preferably coaxial to the opening 16 in the casing 60 and is held in place by a snap ring 29.
  • the snap ring 29 is located in a snap ring groove 31 milled in the wall of the interior bore of the button 14.
  • Piston 12 includes two radial piston grooves 32 and 33 formed in the exterior cylindrical surface of the piston 12.
  • the first of the two piston grooves is a circumferential securing or locking groove 32 which is positioned adjacent the inner end 27 of piston 12 to be engaged by the snap ring 29 when the piston is fully extended.
  • the second of the two grooves is a circumferential retaining groove 33 positioned adjacent the distal end 28 of the cylinder 12 to be engaged by the snap ring 29 when the piston is in the retracted or running position as shown in Figure 4. As the piston 12 is illustrated in Figure 5 in the extended position, the snap ring 29 is engaged in the radial locking groove 32.
  • the snap ring 29 is made of a strong resilient material arranged to expand into the snap ring groove 31 when forced outwardly and to collapse when unsupported into the grooves 32 and 33 when aligned therewith.
  • a particular arrangement of snap ring and grooves is shown in greater detail in Applicants' copending U.S. Application Serial No. 08/051,032, incorporated herein by reference.
  • the piston moves out into the annular space of the wellbore. Once the piston encounters the wellbore wall, it will then lift the casing off of the wellbore to centralize the casing until such time as the snap ring 29 aligns with and expands into the locking groove 32.
  • the pistons should be of such a length that the pistons can be fully deployed to the locking groove 32 while giving the maximum amount of centralization. Once the pistons are fully deployed, the inner surface 25 on the plug 19 will be substantially clear of the casing bore for all practical purposes, and the casing bore should be substantially full opened.
  • the button 14 further includes a sealing arrangement to provide a pressure tight seal between the piston 12 and the button 14.
  • the button 14 includes two O-rings, 34 and 36, which are positioned on either side of the snap ring 29 in O-ring grooves 37 and 38, respectively.
  • the O-rings 34 and 36 seal against the exterior of piston 12 to prevent fluids from passing from one side of the casing wall to the other through the bore of the button 14.
  • the O-rings 34 and 36 must slide along the exterior of the piston 12 passing the piston grooves 32 and 33 while maintaining the pressure tight seal.
  • the piston 12 further includes an outwardly tapered enlarged diameter peripheral edge 39 on its inner end 27, which edge 39 is larger than the bore in button 14 that receives the piston 12.
  • edge 39 serves as a stop against the button 14 to limit the outward movement of the piston 12.
  • the inside face of button 14 includes a chamfered edge 41 for engaging the outwardly tapered peripheral edge 39 on the piston when the inner end 27 of the piston is approximately flush with the inner end face of the button 14.
  • the inwardly facing rounded surface 25 of the initiator plug extends slightly into the bore of the casing for purposes to be described so that it is substantially clear of the bore to render the casing bore fully open to permit passage of the deploying device 82 or other similar device such as packers or the like that would be passed through the bore of a casing string.
  • the inner bore 18 of the piston 12 is shown having a shaped charge insert installed therein.
  • the shaped charge insert includes a cup-shaped canister or carrier 46 which is sized to be press fit into the bore 18 of the piston 12.
  • a locking compound is used to hold.the canister 46 in the bore cavity of the piston.
  • the carrier 46 is nested against a shoulder 47 in the piston bore 18, the shoulder 47 being the end of the threads 22 which are cut in the bore 18 of the piston at its inner end to receive plug 19.
  • An ignition hole 48 is formed in the inner wall 49 of the cup-shaped carrier 46.
  • a thin metal foil 51 is placed over the outer surface of hole 48 facing the plug 19.
  • an outer end cap 54 is fitted within a recessed shoulder 55 and is held in place by its press fit and a locking compound.
  • a shaped charge 58 is positioned in the canister 46 with a conical depression 59 in the distal end of the face of the shaped charge facing outwardly.
  • the opposite inner end of the piston 12 has the plug 19 enclosing the inner end.
  • the plug 19 has a cylindrical recess 62 which is formed from the inner side of the plug 19 for receiving a detonator cup 64.
  • the cup 64 is held in place within the recess 62 by means of a thread locking compound or the like.
  • the recess 66 may be for example 1/8 inch in diameter and approximately .040 inches deep to leave an integral rupture disc portion 68 formed between the recesses 62 and 66.
  • the rupture disc may be on the order of .0275 inches thick.
  • the cup 64 which is assembled within the recess 62 has provided within its interior bore a detonating system which is comprised of an air space 70, a plug of lead azide 72, and a plug of RDX explosive 74
  • the centralizing piston 12 is shown having been moved to an extended and locked position wherein the distal end 28 of the piston is in contact with the bore hole wall.
  • a deploying device 82 such as is shown in Figure 1 has been moved through the interior bore of the casing string to contact the outer surface 25 of plug 19 on the inner end of the piston.
  • the perforating apparatus is now in a position to permit perforation of the formation which the wellbore traverses.
  • the pistons 12 may be extended by the application of hydraulic pressure to the interior of the casing pipe string which provides a force that impinges on the inner end of the piston to move the pistons outwardly.
  • one particular advantage of the apparatus described herein is that the centralizing piston and a button 14 which guides the piston, when provided, may be assembled within the casing string at some time just before the casing is run into the wellbore W. Accordingly, the handling of the casing pipe up to the point that it is being installed in the wellbore is not subjected to the danger which would be caused by having the explosive devices installed during shipping and handling of the casing prior to its installation. It is also to be noted that there is no device present within the system thus far described to initiate the explosive device within the piston so that such handling in the configuration described above is considered safe and will not unnecessarily endanger the personnel who are installing the devices in the casing or installing the casing within the wellbore.
  • FIG. 6 of the drawings the casing 60 is shown having been run into a well.
  • the centralizers are shown having been extended by means of a pumpable activator device 82 such as shown in Figure 1 or by the application of hydraulic pressure to the casing string at the surface. Hydraulic activation is accomplished by closing a valve at the base of the casing string and applying the necessary activation or deploying force required to move the pistons from the retracted position to the extended position. Accordingly, pumps or other pressure generating mechanism would provide the necessary deploying force for the pistons.
  • an annulus of cement can be injected and set around the entire outer periphery of the casing, over some appropriate interval of casing, to seal the casing from the formation.
  • the casing string with the centralizer system as described is arranged so that in those portions of the wellbore where it is desired to have a centralizing only function for the centralizers, the centralizers are not configured so as to provide a perforating function.
  • the centralizers are of the embodiment shown in Figures 4 and 5 which include a shaped charge device or the like for perforating the formation to be produced.
  • the centralizers 50 In the initial installation of the casing within the wellbore, it is important to note that when the centralizers are not extended the casing can be rotated and reciprocated to work past tight spots or other interferences in the hole. These retracted centralizers 50 also do not interfere with the fluid path through the casing string so that fluids may be circulated through the casing to clear cuttings from the end of the casing string. Also the casing interior can be provided with fluids that are less dense than the wellbore fluids, in the annular space, causing the casing string to float. Clearly, the centralizers 50 of the present invention permit a variety of methods for installing the casing into its desired location in the wellbore.
  • the centralizers are deployed to centralize the casing. As discussed above, there are several methods of deploying the centralizers. Once the pistons are all deployed and the snap rings have secured them in the extended fixed position projecting outwardly toward the wall of the wellbore, the cement may be injected by well known techniques into the annulus formed by the centralizing of the casing within the borehole.
  • the cement around casing 60 may be allowed to set while the production string is assembled and installed into the casing. It is important to note that at this point in the process of establishing the well, the casing and wellbore are sealed from the formation. Accordingly, there is as yet no problem with controlling the pressure of the formation or with loss of pressure control fluids into the formation.
  • the perforation string is assembled to create perforations in the casing adjacent to the hydrocarbon bearing zone. Accordingly, high density fluids are provided in the wellbore to maintain a sufficient pressure head against the affect of formation pressure to avoid a blowout situation. While the production string is assembled and run into the well some of the wellbore fluids, in an overbalance condition, may be forced into the formation.
  • the production string must be installed quickly to begin producing the well once the well has been perforated.
  • the production string may be assembled and installed in the casing before perforation of the formation is performed.
  • the packer 86 as shown in Figure 6 seals off the casing string annulus between the production tubing 89 and the casing 60. This packer is set above the pistons 50 to be opened as flow paths.
  • production may begin when communication is established with the formation, such as by perforation in any under balanced condition.
  • centralizing pistons 50 may be made so that they can be opened to serve as a flow path by means of chemical activation as opposed to explosive activation. Such an arrangement is described in U.S. Patent 5,228,518. This may be accomplished for example, by having the closures at each end of the piston bore made of a material that is dissolvable in a fluid. If plug 19 and end cap 54 are made of magnesium or aluminum an acid solution can be used to rapidly dissolve these materials.
  • Figure 6 shows an apparatus and system for initiating the detonators within the detonator cup 64 ( Figure 5) in the pistons, in order to fire the shaped charges and penetrate the formation. Firing the detonators will also open the piston to fluid flow between the formation and casing string.
  • a small diameter pipe string such as production tubing 76 or coiled tubing is run into the interior of the casing string after the centralizers 50 are extended but before the detonators are fired.
  • the casing string may be in the form of a longstring which extends from the bottom of the wellbore to the surface or in the form of a liner where the casing is required over some specific zone in the wellbore which does not extend to the surface.
  • Such a liner is normally set using drill pipe.
  • the casing may or may not be cemented in place.
  • a primer cord 84 may be pre-installed in the lower end of the tubing string 76 and run into the well with the tubing string.
  • the tubing string may be located in the casing string and then the primer cord is run into the tubing string.
  • the bottom of the tubing string can be provided with a latching mechanism 93.
  • a sinker bar with primer cord trailing behind can be lowered into the tubing string and latched inside of the tubing.
  • a device can be pumped to the latch 93 with a primer cord trailing.
  • a perforating head 89 would be run at the trailing, upper end of the primer cord 84 to provide a means for initiating the primer cord.
  • a production packer 86 can be set.
  • a sinker bar 91 can be dropped which would strike the perforating head and initiate the primer cord.
  • a wireline could be connected with the primer cord or perforating head in order to initiate the primer cord.
  • the primer cord is initiated by dropping a similar bar 91 or using an electrical wireline or as another alternative, using a hydraulically actuated perforating head. Once the primer cord is initiated, it results in the development and propagation of a pressure wave within the pipe string 76. This pressure wave is then communicated through the fluid in the pipe 76 and casing 60 to the plug 19 at the inner end of the cylinders 12. If necessary, the pipe string 76 may be centered in the casing by means of conventional centralizers 78. Centering the pipe string 76 in the casing string may be important in view of the importance of propagating a pressure wave to the cylinders 12 on all sides so that the force of this pressure wave is sufficient to rupture the disc 68 in the plug 19.
  • This rupture of disc 68 will sequentially initiate the powders 72 and 74 within the cup 64 positioned in the plug 19. Tests have shown that initiation of the detonator will take place without the provision of an air space 70 in the cup 64 by locating powders adjacent to the ruptured disc 68. The amount of pressure required to rupture the disc is increased when the air space is eliminated; however, detonation does take place. It is believed that the principle behind the detonation is an adiabatic compression within the cup 64 which is sufficient to initiate the powders 72, 74 therein. Therefore, it appears to only be necessary to generate sufficient pressure within the interior of the casing bore to cause the rupture disc 68 to rupture which will thereby initiate the detonator housed within the cup 64.
  • a shaped charge When a shaped charge is present in the piston 12, initiation of the detonator is communicated through the opening 48 within the carrier 46 to detonate the shaped charge 58. This detonation produces a penetrating force that is directly applied to the formation F so that all the outwardly directed energy of the shaped charge is applied to perforation and fracturing of the formation. Detonation of the shaped charge 58 also removes the plug 19 and end cap 54 to open the piston 12 for fluid flow.
  • the smaller diameter pipe 76 housing the primer cord may be provided with slots or holes in the outside walls thereof to facilitate transmission of a pressure wave emanating from the primer cord to the perforating cylinders 12.
  • a pressure wave may be propagated through the walls of solid pipe which is sufficient to initiate the detonators within the plug 19 on the cylinders 12.
  • the system shown in Figure 6 with a production packer 86 set in place will permit the completion to take place with an under-balanced fluid in the pipe string, so that upon perforation of the formation F formation, fluids may be readily received into the casing string through the now open cylinder 12 and from there into the production tubing 76 for conveyance to the surface.
  • penetrating is used to describe the process for opening a communication path into the formation.
  • the reason that penetrating the formation is desirable is that the permeability of porous reservoir rock is usually reduced or plugged near the wellbore due to the leakage of drilling fluids used in the drilling operation into the first few inches of the formation material surrounding the wellbore. This reduces permeability near the wellbore and is referred to as skin damage.
  • the shaped charges are not designed to make a hole in the casing as in a normal perforating system, but rather to establish communication with the reservoir rock and to penetrate the rock itself with a fracturing and penetrating blast that extends communication beyond the skin damage.
  • normal shape charges in a perforating system are positioned within the casing string and must therefore progress through the fluids within the casing string, the steel casing string wall, cement if it is in place, and then into the skin damaged portion of the reservoir.
  • the shape charge is positioned directly against the formation and thus a much greater portion of the energy developed by the shaped charge is applied to the formation rock itself.
  • a primer cord into the interior of either a casing pipe string or a production string in order to initiate the pressure wave described herein for detonating the perforation devices.
  • the primer cord could be pumped in behind a pumpable plug or the like to position the primer cord into a horizontal reach of pipe. In a vertical or nearly vertical pipe section, gravity would be sufficient to lower a primer cord weighted on its lower end, into a pipe string.
  • other methods could be used to develop a pressure wave for initiating the shaped charge.
  • detonators might be used to initiate the explosion of the shaped charged within the centralizing cylinder 12.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (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)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)

Abstract

Un système de conditionnement d'un puits de forage comprend l'utilisation d'un dispositif (50) déclenché au fond du forage et transporté par tubage afin d'établir une voie de communication fluidique entre l'intérieur d'une colonne de tubage (60) et une formation terrestre (F) traversée par le trou de forage (W). Des dispositifs (50) d'établissement de voie d'écoulement sont montés dans la paroi de la colonne de tubage (60) et sont sélectivement ouverts lorsque la pression dans la colonne est inférieure à celle de la formation. Ces dispositifs (50) peuvent comprendre des charges explosives (58, 72, 74) disposées dans la paroi de la colonne. La détonation des charges explosives (58, 72, 74) peut être provoquée par une impulsion ou une onde de pression.
PCT/US1993/009688 1993-10-07 1993-10-07 Appareil et procede declenches au fond d'un forage, pour le conditionnement d'un puits de forage WO1995009967A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PCT/US1993/009688 WO1995009967A1 (fr) 1993-10-07 1993-10-07 Appareil et procede declenches au fond d'un forage, pour le conditionnement d'un puits de forage

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US1993/009688 WO1995009967A1 (fr) 1993-10-07 1993-10-07 Appareil et procede declenches au fond d'un forage, pour le conditionnement d'un puits de forage

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WO1995009967A1 true WO1995009967A1 (fr) 1995-04-13

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Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5505260A (en) * 1994-04-06 1996-04-09 Conoco Inc. Method and apparatus for wellbore sand control
US7152676B2 (en) 2002-10-18 2006-12-26 Schlumberger Technology Corporation Techniques and systems associated with perforation and the installation of downhole tools
US7493958B2 (en) 2002-10-18 2009-02-24 Schlumberger Technology Corporation Technique and apparatus for multiple zone perforating
US7753121B2 (en) 2006-04-28 2010-07-13 Schlumberger Technology Corporation Well completion system having perforating charges integrated with a spirally wrapped screen
US8151882B2 (en) 2005-09-01 2012-04-10 Schlumberger Technology Corporation Technique and apparatus to deploy a perforating gun and sand screen in a well
WO2017099604A1 (fr) * 2015-12-09 2017-06-15 Tyrfing Innovation As Dispositif de vérification et de centrage d'élément tubulaire de fond, et procédé

Citations (4)

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Publication number Priority date Publication date Assignee Title
US3326291A (en) * 1964-11-12 1967-06-20 Zandmer Solis Myron Duct-forming devices
US3468386A (en) * 1967-09-05 1969-09-23 Harold E Johnson Formation perforator
US4541486A (en) * 1981-04-03 1985-09-17 Baker Oil Tools, Inc. One trip perforating and gravel pack system
US4616701A (en) * 1985-06-06 1986-10-14 Baker Oil Tools, Inc. Well perforating apparatus including an underbalancing valve

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3326291A (en) * 1964-11-12 1967-06-20 Zandmer Solis Myron Duct-forming devices
US3468386A (en) * 1967-09-05 1969-09-23 Harold E Johnson Formation perforator
US4541486A (en) * 1981-04-03 1985-09-17 Baker Oil Tools, Inc. One trip perforating and gravel pack system
US4616701A (en) * 1985-06-06 1986-10-14 Baker Oil Tools, Inc. Well perforating apparatus including an underbalancing valve

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5505260A (en) * 1994-04-06 1996-04-09 Conoco Inc. Method and apparatus for wellbore sand control
US7152676B2 (en) 2002-10-18 2006-12-26 Schlumberger Technology Corporation Techniques and systems associated with perforation and the installation of downhole tools
US7493958B2 (en) 2002-10-18 2009-02-24 Schlumberger Technology Corporation Technique and apparatus for multiple zone perforating
US8151882B2 (en) 2005-09-01 2012-04-10 Schlumberger Technology Corporation Technique and apparatus to deploy a perforating gun and sand screen in a well
US7753121B2 (en) 2006-04-28 2010-07-13 Schlumberger Technology Corporation Well completion system having perforating charges integrated with a spirally wrapped screen
WO2017099604A1 (fr) * 2015-12-09 2017-06-15 Tyrfing Innovation As Dispositif de vérification et de centrage d'élément tubulaire de fond, et procédé
GB2562649A (en) * 2015-12-09 2018-11-21 Tyrfing Innovation As A downhole tubular verification and centralizing device, and method

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