WO2022192979A1 - Système tout-en-un et procédé associé pour la fracturation et la complétion d'un puits qui installe automatiquement des tamis à sable pour une régulation de sable immédiatement après fracturation - Google Patents

Système tout-en-un et procédé associé pour la fracturation et la complétion d'un puits qui installe automatiquement des tamis à sable pour une régulation de sable immédiatement après fracturation Download PDF

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Publication number
WO2022192979A1
WO2022192979A1 PCT/CA2021/050345 CA2021050345W WO2022192979A1 WO 2022192979 A1 WO2022192979 A1 WO 2022192979A1 CA 2021050345 W CA2021050345 W CA 2021050345W WO 2022192979 A1 WO2022192979 A1 WO 2022192979A1
Authority
WO
WIPO (PCT)
Prior art keywords
sliding sleeve
tubular liner
actuation member
fracking
frac
Prior art date
Application number
PCT/CA2021/050345
Other languages
English (en)
Inventor
Sean P. Campbell
Daniel Rojas
David Speller
Original Assignee
Sc Asset Corporation
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 Sc Asset Corporation filed Critical Sc Asset Corporation
Priority to PCT/CA2021/050345 priority Critical patent/WO2022192979A1/fr
Publication of WO2022192979A1 publication Critical patent/WO2022192979A1/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
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • 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
    • E21B43/02—Subsoil filtering
    • E21B43/08—Screens or liners
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/08—Down-hole devices using materials which decompose under well-bore conditions

Definitions

  • the present invention relates to a system and method for fracking a hydrocarbon formation and completing a well for production, and more particularly relates to a system and method which immediately after completion of fracking automatically locates a sand screen at an opened port in a production string to prevent ingress of sand from the hydrocarbon formation to allow of subsequent immediate production.
  • Part of the completion process typically firstly includes a fracking operation.
  • Fracking involves injection of high pressure fluids (namely incompressible liquids, often containing proppants) into the hydrocarbon formation/reservoir to initiate fractures within the surrounding rock to increase porosity of “tight” formations and thereby increase the ability of hydrocarbons within the formation to flow from within a hydrocarbon formation.
  • high pressure fluids namely incompressible liquids, often containing proppants
  • Fracking operations for completing a well within a reservoir may increase production from the well by many multiples in a given time period, in some cases up to 3x or greater if conducted over the entire length of a horizontal wellbore as compared to what would otherwise have been the case if a fracking operation had not been completed.
  • the fracking process can be a very important and critical step in preparing a wellbore for production.
  • Fracking fluid may contain various adjuvants such as acids and/or diluents to increase followability of the oil/gas from the formation.
  • fracking fluids commonly contain proppants such as fine sand (frac sand) or ceramic beads of consistent and engineered uniform diameter to uniformly “prop” open the created fractures and maintain such fractures in the formation so that hydrocarbons may better flow from the formation.
  • proppants such as fine sand (frac sand) or ceramic beads of consistent and engineered uniform diameter to uniformly “prop” open the created fractures and maintain such fractures in the formation so that hydrocarbons may better flow from the formation.
  • Sand screens are known in the art, and are typically inserted within a production string, typically after the tripping out of the frac string from the well , when a production string having a sand screen covering open ports on such production string is then separately “run in” into the wellbore.
  • US 9,976,394 along with US 20180320488 each entitled “System and Methods for Fracking and Completing a Well which Flowably Installs Sand Screens for Sand Control’, each commonly invented with the within application and commonly assigned to the present applicant, both disclose use of actuating members to selectively engage a respective desired sleeve covering associated ports along the production string. Thereafter, under influence of uphole-applied pressure, the actuating members cause such respective sleeves to be slidably moved downhole to expose an open port in the production string. Fracking fluid is then injected in the production string to frac the formation in the region of the opened port(s).
  • flowable sand screen subs are thereafter flowed downhole to cover the respective opened port(s) and thereby prevent sand from flowing into the opened port(s) and allow only hydrocarbons from the formation to flow into the production string via the opened port(s).
  • US 2019/0353005 (now US 10,648,285) entitled “ Fracturing System and Method” to Baker Hughes teaches a fracturing sleeve having both an opening sleeve and a closing sleeve, which as disclosed and as shown in Fig. 2A-2B (item 44) and col.2 line includes a sand screen spaced from the opening sleeve and disposed in the same zone as the opening sleeve, which may be subsequently actuated via a pumpable actuating member to cause a screen to be slid over an opened port for sand control.
  • an “all-in-one” well fracking and completion system which allows flowing into a tubular string one actuating member per port which is fracked, which allows not only fracking of the reservoir at the given port but further without pulling the tubular string automatically installs a sand screen and thus be able to immediately thereafter produce from such port.
  • a tubular string used for fracking need not be “tripped out” after a fracking step in order to complete the well and allow production from the well after fracking operations.
  • sand from a hydrocarbon formation containing oil sand as well as additional sand resulting from conducting a fracking operation be substantially prevented from entering a wellbore during production operations and otherwise detrimentally affecting pumping equipment, to say nothing of increased costs of disposing of such sand .
  • uphole and downhole with regard to a particular component of the system, or with respect to the method of the present invention, is a reference to a location on the component within a wellbore where uphole means in the direction of the surface along a wellbore, and “downhole” is the correspondingly opposite direction towards a toe of the wellbore.
  • unique profile herein shall be construed as including, but not limited to, a unique longitudinal width dimension.
  • the present invention comprises a system for fracking a hydrocarbon formation at a given location along a wellbore, comprising;
  • tubular liner insertable within said wellbore, said tubular liner having an interior bore and further comprising:
  • an elongate substantially cylindrical hollow collet sleeve having a radially- outwardly biased protuberance on a periphery thereof having a first unique profile, said radially-outwardly biased protuberance configured to matingly engage said interior circumferential groove or profile on a corresponding one of the plurality of sliding sleeve members;
  • a dissolvable or burstable plug member which for a limited time or up to a specified pressure, prevents pressurized fluid injected downhole in said interior bore from travelling through said actuation member thereby allowing said actuation member to be forcibly flowed downhole in said tubular liner by said pressurized fluid;
  • a spring member situated adjacent to said sand screen member, adapted to be forcibly compressed by said sand screen member when pressurized fluid is applied to an uphole end of said cylindrical actuation member and to be decompressed upon removal of pressurized fluid and thereafter longitudinally slidably reposition said sand screen member within said tubular liner; wherein when said cylindrical actuation member having said unique profile thereon has been flowed downhole in said tubular liner by pressurized fluid and has selectively engaged said desired sliding sleeve member having a corresponding unique profile thereon and caused said sliding sleeve to move downhole so as to open said frac port, said spring member is compressed so as to permit said sand screen member to be longitudinally positioned within said tubular member so as not to cover said opened frac port thereby allowing unobstructed flow of said pressurized fluid through said frac port; and wherein when said pressurized fluid is ceased being applied to said actuation member, said spring member immediately decompresses
  • the above system provides for the immediate installation of a sand screen at such given location of an opened port without having to “trip out” a frac string prior to commencing production at such location, and further provides for the use of only one actuation member, and not having to flow downhole a second member having a sand screen thereon.
  • each of the sliding sleeve members are configured so as to lockingly engage the tubular liner when the respective sliding sleeve members are each respectively moved so as to uncover a corresponding frac port .
  • the sliding sleeve members once in said open position, are thereby prevented from thereafter inadvertently returning to a closed position and covering the opened port in the tubing liner. Absence of this feature would mean that the slidable sleeve could potentially close, thus preventing oil from being produced from such (now closed) port along the tubular liner.
  • the locking engagement comprise mating engagement means on both the sliding sleeve members and on the tubular members.
  • the mating engagement means on the sliding sleeve members comprise a plurality of collet fingers, radially outwardly biased, and extending from a downhole end of each sliding sleeve member
  • the corresponding mating engagement means on the tubular liner comprises an annular circumferential ring on the tubular liner, which when one of said slibable sleeve members is caused to be moved to the open position, the radially outwardly-biased collet fingers, and in particular protuberances on respective distal ends of such collet fingers, matingly engage said annular circumferential ring on said sliding sleeve member so as to lockingly engage and secure the sliding sleeve member in the open positon to the tubular string.
  • Other manners of providing mating engagement of each sliding sleeve with the tubular liner will now be apparent to persons of skill in the art and are specificially contemplated as part of the within invention.
  • the unique profile of the radially-outwardly biased protuberance on the actuation member is of a unique width Wl
  • the interior circumferential groove on the mating sliding sleeve is of a width equal to or greater than Wl.
  • the system for fracking and completing a well in a hydrocarbon formation of the present invention further comprises: a second actuation member, insertable within the interior bore of the tubular liner, comprising: (I) an elongate substantially cylindrical hollow collet sleeve, having a radially- outwardly biased protuberance on a periphery thereof having a second unique profile of width W2 where W2 ⁇ Wl, where the radial ly-outwardly biased protuberance is configured to matingly engage the interior circumferential groove or profile on another of the plurality of sliding sleeve members and is of a width equal to or greater than W 2 but less than W 1 ;
  • a dissolvable or burstable plug member which for a limited time when exposed to dissolving fluid or up to a specified pressure, prevents pressurized fluid injected downhole in said tubular string from travelling through the actuation member, thereby allowing the second actuation member to be forcibly flowed downhole in the tubular liner by the pressurized fluid;
  • a spring member situated adjacent to said sand screen member, adapted to be forcibly compressed by said sand screen member when pressurized fluid is applied to an uphole end of the cylindrical actuation member and to be decompressed upon removal of pressurized fluid and to then longitudinally slidably reposition the sand screen member within said tubular liner ; wherein when the cylindrical actuation member having said unique profile thereon has been flowed downhole in the tubular liner by pressurized fluid and has selectively engaged the desired sliding sleeve member having a corresponding unique profile thereon and caused the sliding sleeve to move downhole so as to open the associated frac port, the spring member on the actuation member is compressed so as to permit the sand screen member to be longitudinally positioned along said actuation member in a region within said tubular member so as not to cover the opened frac port, thereby allowing unobstructed flow of said pressurized fluid through said frac port during a fracking operation; and wherein when
  • the radial ly-outwardly biased protuberance on the actuation member may be configured such that after matingly engaging the interior circumferential groove or profile on the respective sliding sleeve member it remains lockingly engaged with the interior circumferential groove or profile on said slidable sleeve.
  • the actuation member is prevented from further movement within said tubular liner, and thus the sand screen thereon remains fixed in the open position with the associated frac port and all oil flowing into the tubular liner via such port will necessarily be required to pass through such sand screen .
  • the dissolvable or burstable plug member is a dissolvable plug member which is dissolvable upon a dissolving fluid being provided to the interior bore of the tubular liner.
  • the dissolvable plug member may further comprise a dissolvable ball which may be flowed downhole in the tubular liner, and which after being exposed to a dissolving fluid, after a passage of time dissolves so as to allow flow of bitumen along the tubular string.
  • Composition of balls which may dissolve in time, and corresponding fluid which may cause such dissolution are well known to persons of skill in the art, and are thus not further discussed in detail herein.
  • the cylindrical actuation member further comprises a seating surface, configured to provide a sealing surface against which said dissolvable or burstable plug member may abut, which sealing surface in combination with said plug member, at least for a limited time, prevents pressurized fluid from travelling through said actuation member.
  • such invention comprises a cylindrical actuation member, insertable within a tubular liner for use when fracking a hydrocarbon formation at a given location along the tubular liner, which after opening a port and after a fracking step, immediately locates a sand screen member at said location without having to “trip out” a frac string prior to commencing production, comprising:
  • an elongate substantially cylindrical hollow collet sleeve having a radially- outwardly biased protuberance on a periphery thereof having a unique profile, said radially-outwardly biased protuberance configured to matingly engage an interior circumferential groove on a corresponding one of a plurality of sliding sleeve members within said tubular liner;
  • a seating surface configured to provide a sealing surface against which a dissolvable or burstable plug member may abut, which sealing surface in combination with a plug member, at least for a limited time, prevents pressurized from travelling through the actuation member;
  • a spring member situated adjacent to and downhole of the sand screen member, adapted to be forcibly compressed by the sand screen member when pressurized fluid is applied to an uphole end of said cylindrical actuation member and to be decompressed upon removal of pressurized fluid against said cylindrical actuation member and to thereafter longitudinally reposition the screen member in an uphole direction.
  • the present invention comprises a method for conducting a fracking procedure at a given location along a wellbore .
  • Such method advantageously locates a sand screen at such location immediately after a fracking step at such location is completed, thereby immediately preventing ingress of any sand into said tubular liner and allowing subsequent production from the formation without having to first “trip out” any frac string insert a production string in order to commence production.
  • Such method comprises the steps of: (i) locating a tubular liner having:
  • the plug member on said actuation member is a burstable disk and such method further comprises the step, after step (v), of injecting a pressurized fluid into said interior bore at a pressure sufficient to rupture said burstable disk, so as to thereafter allow fluid to flow through said first actuation member.
  • step (v) of injecting a pressurized fluid into said interior bore at a pressure sufficient to rupture said burstable disk, so as to thereafter allow fluid to flow through said first actuation member.
  • the method further comprises the step, after step (v) , of injecting a dissolving fluid or using said frac fluid if said frac fluid is a dissolving fluid, to dissolve said dissolvable member so as to thereafter allow fluid to flow through said first actuation member.
  • such method further comprises the step when said first actuation member engages the corresponding sliding sleeve member and moves such sliding sleeve member to the open position, of causing the sliding sleeve member when at said open position to lockingly engage the tubular liner.
  • the step of causing said one of said sliding sleeve members when at said open position to lockingly engage said tubular liner comprises the step, of causing a biased protuberance on said sliding sleeve member to engage a mating groove in said tubular member so as to retain said first sliding sleeve member in a position where the respective associated frac port is uncovered.
  • the said step of causing said one of said sliding sleeve members when moved to said open position to lockingly engage said tubular liner comprises the step of causing a ratchet member on said sliding sleeve to engage a mating ratchet member on said tubular liner, so as retain said one of said sliding sleeve members in a position where the respective associated frac port is uncovered and return movement of the sliding sleeve in an uphole direction is thereby prevented.
  • a shear pin is provided to initially maintain each sliding sleeve initially covering an associated port, so that during insertion of a tubular liner into a well bore any detritus or tailings remaining from drilling the wellbore, or any sand or obstructive material, will be prevented from entering the wellbore.
  • step (iv) of the above method of causing said one sliding sleeve member and first actuation member engaged therewith to together move downhole and uncover and thereby open an associated of said plurality of frac ports further comprises the step of using such applied pressurized fluid to cause a shear pin fixing said sliding sleeve within said tubular liner to shear so as to then allow said one sliding sleeve member and first actuation member engaged therewith to together move downhole within said tubular liner and uncover and thereby open an associated of said plurality of frac ports.
  • the first actuation member when said first actuation member engages said one sliding sleeve member and moves said sliding sleeve member to the open position, the first actuation member may further be caused to lockingly engage the sliding sleeve member, thereby preventing further movement of said actuation member relative to said one of said sliding sleeve members.
  • such method further comprises the steps, after step (vi), of:
  • the method of the present invention be repeated for each port located along the tubular string, and thus the method of the present invention further comprises repeating steps (i)-(v) using a second, third, and consecutive cylindrical actuating members, each having a unique profile mating with a similar unique interior circumferential groove or grooves on the interior of each sliging sleeve, until all of said plurality of spaced-apart ports along the tubular liner have been uncovered, the wellbore tracked at each opened frac port and a sand screen situated at each opened frac port.
  • the most-distal port along the wellbore from surface will be opened first by a first actuation member, and the formation fracked at such location and a sand screen installed, and thereafter the second actuating member will be targeted to the second - lowermost (second most distal) port, and the sequence repeated for each successive port and corresponding sliding sleeve, until the entirety of wellbore has been fracked along its entire length, and sand screens installed at each port after fracking.
  • the unique profile may vary uniquely in terms of the relative width of the protuberance(s) on the actuating member and the corresponding width of the circumferential groove (s) on the interior of the various sliding sleeves.
  • pairs of mating profiles may be a series of protuberances and circumferential interior mating grooves, each of varying widths and/or spacing relative to other pairs of actuating members and sliding sleeves, to provide unique engagement of one actuating member with a unique sliding sleeve to open a port at a desired length along .
  • the radially -outwardly biased protuberance of said first actuation member is of a width W1
  • said resiliently-outwardly biased protuberance of said second actuation member is of a width W2, wherein W2 ⁇ W 1.
  • Fig. 1 is a schematic view of a typical wellbore having a tubular liner inserted therein, further having a plurality of ports, with each port having a corresponding sliding sleeve initially covering the associated port;
  • Fig. 2A-2E are a series of sequential cross-sectional sections of a production tubing string, showing the various sequential positions of a sliding sleeve in the region of a port on such tubing string, prior to, during insertion of, and after actuation by an activation member, further showing the manner of selective engagement of a unique profile on the actuation member with the particular desired sliding sleeve, and which sliding sleeve uses a ratcheting mechanism to retain the sliding sleeve in the open position once actuated to such position by the actuation member, wherein:
  • Fig. 2A is an enlarged cross-sectional view of the tubing liner, associated port and sliding sleeve of area 'A' of Fig. 1 prior to flowable insertion into the tubing liner of an actuating member and prior to the sliding sleeve being moved downhole;
  • Fig. 2B is an enlarged similar cross-sectional view of the tubing liner, associated port and sliding sleeve shown of area 'A' of Fig. 1, after a first actuating member has been flowed downhole in the tubing liner and lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner;
  • Fig. 2C is an enlarged cross-sectional view of the tubing liner, associated port and sliding sleeve was shown in area 'A' of Fig. 1, after a first actuating member has been flowed downhole in the tubing liner, lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner, and further has moved the sliding sleeve to a position uncovering the port and thereby opening the port;
  • Fig. 2D. is an enlarged cross-sectional view of the tubing liner, associated port and sliding sleeve was shown in area 'A' of Fig. 1, after a first actuating member has been flowed downhole in the tubing liner, lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner, and further has moved the sliding sleeve to an open position uncovering the port, and fluidic pressure acting on the plug member has been removed and the actuating member via a spring member thereon then slidably positioned a screen underneath the opened port; and
  • Fig. 2E is an enlarged cross-sectional view of the tubing liner, associated port and sliding sleeve was shown in area 'A' of Fig. 1, after a first actuating member has been flowed downhole in the tubing liner, lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner, and further has moved the sliding sleeve to an open position uncovering the port, and fluidic pressure acting on the plug member has been removed, and the actuating member slidably positioned a screen underneath the opened port, and the plug member has been dissolved;
  • Fig. 3A-3E are a series of enlarged sequential cross-sectional sections of a production tubing string, showing the various sequential positions of a sliding sleeve in only the region of a port on such tubing string, prior to, during insertion of, and after actuation by an activation member, wherein: Fig. 3A is an enlarged view of the circled area 's' in Fig. 2A;
  • Fig. 3B is an enlarged view of the circled area 's' in Fig. 2B;
  • Fig. 3C is an enlarged view of the circled area 't' in Fig. 2C;
  • Fig. 3D is an enlarged view of the circled area 'u' in Fig. 2D;
  • Fig. 3E is an enlarged view of the circled area 'v' in Fig. 2E;
  • Fig. 4A-4E are a series of sequential partial cross-sectional sections of the same production tubing string, showing the various sequential positions of a sliding sleeve in the region of a port on such tubing string, prior to, during insertion of, and after actuation by an activation member, further showing the manner of selective engagement of a unique profile on the actuation member with the particular desired sliding sleeve, and which uses a ratcheting mechanism to retain the sliding sleeve in the open position once actuated to such position by the actuation member, wherein:
  • Fig. 4A is a full sectional view of the tubular liner, associated port and sliding sleeve of Fig. 2 A, prior to flowable insertion into the tubing liner of an actuating member and prior to the sliding sleeve being moved downhole;
  • Fig. 4B is a full sectional view of the tubular liner associated port and sliding sleeve of Fig. 2B, showing the actuation member in non- sectional and after such actuating member has been flowed downhole in the tubing liner and lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner;
  • Fig. 4C is a full sectional view of the tubular liner in the area of an associated port and sliding sleeve after flowable insertion of an actuating member and after the actuating member has lockingly engaged the locking sleeve having a similar unique mating profile as the actuating member, and after the sliding sleeve has been repositioned downhole;
  • Fig. 4D is a full sectional view of the tubular liner in the area of an associated port and sliding sleeve after a first actuating member has been flowed downhole in the tubing liner, lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner, and further has moved the sliding sleeve to an open position uncovering the port, and fluidic pressure acting on the plug member has been removed and the actuating member slidably positioned a screen underneath the opened port; and
  • Fig. 4E is a full sectional view of the tubular liner in the area of an associated port and sliding sleeve after a first actuating member has been flowed downhole in the tubing liner, lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner, and further has moved the sliding sleeve to an open position uncovering the port, and fluidic pressure acting on the plug member has been removed and the actuating member slidably positioned a screen underneath the opened port, and the plug member has been dissolved;
  • Fig.s 5A-5E are sequential cross-sectional views of another fracking system of the present invention similar to the fracking system as shown in Fig. 2A-2E, showing the various sequential positions of a sliding sleeve in the region of a port on such tubing string, prior to, during insertion of, and after actuation by an activation member, further showing the manner of selective engagement of a unique profile on the actuation member with the particular desired sliding sleeve, but with an alternative different configuration for keeping the sliding sleeve in locking engagement with the tubular liner not employing a ratchet mechanism but rather the engagement of a mating protuberance;
  • Fig. 6A is a cross-sectional view of the actuation member, being one embodiment of the present invention, immediately prior to being provided with an additional plug member and being flowed downhole;
  • Fig. 6B is a similar cross-sectional view of the actuation member of the present invention, wherein the plug member has dissolved, and the sand screen thereon been extended so as to be deployed in a position within the interior of the tubular string below a desired port therein;
  • Fig. 7 is an enlarged full cross-sectional view of the tubing liner, associated port and sliding sleeve of the invention shown of area 'A' of Fig. 1, and Figures 2B-2E, after a first actuating member has been flowed downhole in the tubing liner and lockingly engaged the sliding sleeve covering such lowermost (most distal) port in the tubing liner, but prior to fluid pressure exerted on the plug member having sheared the shear pins and compressed the spring;
  • Fig. 8 is a view of the tubing liner, associated port and sliding sleeve shown of Fig. 7, immediately after uphole fluid pressure exerted on the plug member has caused the shear pins securing the sand screen to the actuation member to be sheared and the spring become further compressed (even though the port has been partially opened);
  • Fig. 9 is a subsequent view of the tubing liner, associated port and sliding sleeve shown in Fig. 8, after fluid uphole pressure has further caused the actuation member engaged with the sliding sleeve to move downhole to fully open the port, and the ratchet member on the sliding sleeve engaged the ratchet member on the tubing string thereby preventing further return uphole of the sliding sleeve;
  • Fig. 10 is a subsequent view of the tubing liner, associated port and sliding sleeve shown in Fig. 9, after uphole fluid pressure has further ceased or been substantially reduced, and the spring on the actuation member caused the sand screen on the actuation member to be re-located uphole so as to have at least a portion of the sand screen situated substantially underneath and disposed below the opened port;
  • Fig. 11 is a subsequent view of the tubing liner, associated port and sliding sleeve shown in Fig. 10 after sand has flowed into the opened port but not been allowed, due to the sand screen, to flow into the interior bore of the tubing liner; and
  • Fig. 12 is a flow diagram illustrating one broad embodiment of the method of the present invention for fracking through a selected port and thereafter automatically installing a sand screen at such port location along a tubing string, upon cessation of the fracking step.
  • Fig. 1 is a schematic diagram of a typical wellbore 12 drilled within a hydrocarbon formation 10.
  • a tubular liner 14 with an interior bore 15 is provided within such wellbore 12, with the tubular liner 14 having a plurality of longitudinally-spaced apart frac ports 16 spaced at longitudinal intervals therealong which provide, when open, fluid communication between the interior bore 15 and an exterior of the tubular liner 14.
  • a plurality of cylindrical hollow sliding sleeve members 18 (“sliding sleeve”) are provided within interior bore 15 of and along tubing liner 14, each sliding sleeve 18 configured when in an initial closed position to cover a corresponding of said longitudinally spaced-apart frac ports 16, as shown for example in Fig. 1, 2 A, 3 A, and Fig. 4 A .
  • Each sliding sleeve member 18 is slidably movable longitudinally in the interior bore 15 to an open position to uncover a corresponding frac port 16, as shown for example in Fig. 1, 2C, 3C, and Fig. 4C .
  • each sliding sleeve 18 is provided with an interior circumferential groove or grooves 22 of a unique “key” profile (in this case each groove 22 of a varying width and a varying distance between each groove 22) .
  • each sliding sleeve 18 may comprise a plurality of individual members such as for example individual members 18a, 18b, which as shown in Fig. 7 are threadably jointed together by mating external threads, such as external threads 86 on individual member 18b, and corresponding internal mating threads 88 on individual sliding sleeve member 18a,
  • Configuration of sliding sleeves 18 in such manner wherein they are comprised of a plurality of individual members 18a, 18b threadably joined together provides the significant advantage of allowing easier and less expensive machining of internal grooves 22a, 22b, and 22c on each of the respective individual members 18a, 18b, the purpose of such internal grooves 22 (ie. 22a, 22b, and 22c) being more fully explained herein.
  • an entire production string may comprise a a tubing liner 14 having a series of threadably joined tubing sections 101, with each tubing section 101 having an internally- threaded top sub 19 threadably secured at mating threads 85 to a tubing liner portion 14 at an uphole end thereof , and an externally- threaded bottom sub 21 threadably secured at mating threads 84 to a tubing liner portion 14 at an downhole end thereof.
  • a plurality of shear members 37 are provided, typically shear pins, with at least one shear member 37 extending through the tubing liner 14 into a threaded aperture 37a in each sliding sleeve 18, to initially secure respectively each sliding sleeve 18 to the tubular liner 14 in the initial closed position covering each port, as shown for example in Fig.s 2A & 2B, and 3A & 3C., in order to prevent any tailings or other detritus from entering the tubular liner 14 upon “run in” of such tubular liner 14 into the drilled wellbore.
  • the shear pins 37 shear upon application of a downhole force on the sliding sleeve member 18 after engagement with a unique actuation member 25.
  • Such force is exerted when an actuation member 25 is flowed downhole and then engages a selective sliding sleeve 18, and fluidic pressure applied to an uphole end thereof, as best shown by arrows in Fig. 3B & 3C, applies a pressure on the actuation member 25, and thus on the sliding sleeve 14 to which it is lockingly engaged.
  • At least one actuation member 25 is provided, as can best be seen in Fig.s 4B, 4C, & 4D, as well as Fig.s 6 A& 6B, to actuate a desired sliding sleeve 18 to an open position to allow injection of fracking fluid via a port 16 at a desired location along the tubular string 14 into the formation, and to further, after completion of fracking, allow inflow of oil into the interior bore 15 of tubing liner 14, for subsequent production to surface.
  • Fig.s 6A & 6B as well as from Figs.
  • actuation member(s) 25 each comprise : (i) a substantially hollow collet sleeve portion 33; (ii) a longitudinally-extending sand screen member 40; and (iii) a spring member 42.
  • a plug member 30 which may be a dissolvable plug member 32 such as a dissolvable ball, or alternatively a burs table plug member (not shown), may be flowed into or originally positioned in the actuation member 25, to initially prevent flow of fluids through hollow interior bore 17 of actuation member to allow ;
  • collet sleeve portion 33 of actuation member 25 allows the actuation member 25, when flowed downhole, allows actuation member 25 to selectively engage a desired sliding sleeve 18 along tubing string 14.
  • Collect sleeve portion 33 has at least one radially-outwardly biased protuberance 27 on a periphery thereof having a unique profile for such purpose, which is configured to matingly engage an interior circumferential groove or grooves 22 of similar unique (mating) profile on a corresponding one of the plurality of sliding sleeve members 18, as best shown in Fig.
  • such plug member 30 prevents pressurized fluid injected downhole in said interior bore 15 from travelling through said actuation member 25. Such thereby allows actuation member 25 along with engaged respective sliding sleeve 18 to be forcibly flowed downhole in said tubular liner 14 by the pressurized fluid, as shown by arrow in Fig. 3C.
  • sand screen member 40 forming part of actuating member 25
  • sand screen member 40 is longitudinally slidably moveable along said cylindrical actuation member 25, and is of a longitudinal length sufficient to cover said frac port 16 when slidably positioned beneath it, as shown for example in Fig. 4E.
  • sand screen 40 comprises a perforated screen having a series of apertures therein, and is typically a stainless steel or galvanized member where the apertures therein are of a small enough dimension/diameter to prevent ingress of sand into interior bore 15 but of sufficient diameter to permit ingress of oil into the interior bore 15 of both actuation member 25 and tubing liner 14 to allow such oil to thereafter be pumped or flowed to surface via tubing liner 14.
  • Screen 40 may be attached to and abut a sealing surface member 56 at its uphole end, and be attached or abut, via a coupling member 55, spring 42 at and along its downhole end.
  • spring member 42 is in a preferred embodiment a helical coil spring, as best shown in Fig.s 4B-4E.
  • collet member 43 may be positioned over/around a collet member 43, and is slidably moverable along collet
  • a helical coil spring 42 is situated adjacent to said sand screen member 40, on a downhole side thereof. Coil spring 42 may thus be forcibly compressed by said sand screen member 40 when screen support assembly 43 is forced downhole by fluid pressure applied to an uphole end of actuation member 25, particularly when actuation member 25 and corresponding engaged sliding sleeve 18 are together engaged and further moved to the end of their permitted travel in tubing liner 14, as shown in Fig. 2C, Fig. 3C, & Fig. 4C, whereupon spring 42 is fully compressed.
  • spring 42 Upon cessation of supply of pressurized fluid to an uphole end of actuation member 25 and plug member 30, spring 42 decompresses and slidably repositions sand screen member 40 in an uphole direction so as to position at least a portion of sand screen member 40 of immediately beneath port 16, as best shown in Fig.s 2E, 3E, & 4E.
  • each of said sliding sleeve members 18 and the tubular liner 14 at a location proximate each of said frac ports 16 have mating engagement means which become respectively lockingly engaged when said sliding sleeve members 18 are each respectively moved so as to uncover a corresponding frac port 16.
  • such mating engagement means in one embodiment comprises, on sliding sleeve 18, a series of toothed ratchets 70 on collet sleeve 71, which when sliding sleeve 18 is repositioned downhole by actuation member 25 (see Fig.
  • toothed ratchets 72 are caused to slide over and engage toothed ratchets 72 on tubular liner 14, thereafter keeping sliding sleeve in the new position in tubular liner 14 and preventing sliding sleeve 18 from ever again moving uphole so to cover port 16.
  • the toothed ratchets 70,72 when engaged with each other thereby retain the sliding sleeve members 18, once in the open position, from thereafter returning to a closed position to cover corresponding frac port 16.
  • the mating engagement means on the sliding sleeve members 14 may alternatively comprise a plurality of collet fingers 71 having protuberances
  • the corresponding mating engagement means on the tubular liner 14 may in such embodiment alternatively may comprise an annular circumferential ring 82 on the tubular liner 14 , which when one of said slibable sleeve members 18 travel to the open position, protuberances 80 lockingly engage annular circumferential ring on tubular liner 14, thereby lockingly retaining sliding sleeve member 18 in locking engagement with tubular liner 14 and thus the corresponding port 16 in an open position.
  • Mandrel 66 having external threads 87 thereon, may be threadably secured via internal threads 89 on individual member 18b to individual member 18b forming collet sleeve 71.
  • Mandrel 66 serves to reduce and prevent ingress of sand or detritus into an area proximate ratchets 70 and 72 which could otherwise prevent their engagement, as shown for example in Fig. 7, or alternatively where radially-outwardly biased protuberances 80 are provided on collet fingers 71 to engage grooves 82 as shown in Fig.s 5A-5E, to likewise prevent or reduce ingress of sand in groove 82 which could otherwise prevent locking engagement of protuberances 80 with internal grooves 82.
  • the profile for the radially- outwardly biased protuberance 27b (and particularly where only one radially-outwardly biased protuberance 27b is used on actuation member 25 instead of three, namely 27a, 27b, 27c uniquely spaced between themselves), such radially-outwardly biased protuberance 27b on said actuation member 25 is of a width Wl, and the corresponding interior circumferential groove 22 on sliding sleeve member 18 is of a width equal to or greater than Wl, as shown, to thereby permit mating engagement therebetween.
  • each protuberance 27b on each successively employed actuation member 25 shall each be less than width Wl, such that W1>W2>W3>W4 etc, and the same applies to the associated width of mating annular groove 22 in each of progressively- more-uphole sliding sleeves 18 in tubing liner 14.
  • a second, third , fourth and potentially additional actuation members 25% 25'% 25'” and 25'”% etc. may be similarly utilized, where each are identical to actuation member 25 save and except for a different mating profile such as but not limited to, a progressively lesser width W2, W3, W4, and W5 on the respective collet sleeve portion 33 additional actuation members 25% 25”, 25”' and 25””, etc,, may be used to successively engage and open progressively more uphole sliding sleeves 18 to successively expose ports 16, frac the formation in such region through the opened port, and thereafter immediately install sand screens 40 after completion of the fracking step for each of the respective ports 16.
  • the radially-outwardly biased protuberance 27b on the respective actuation member is configured such that after matingly engaging the interior circumferential groove or profile 22 on the corresponding sliding sleeve member 18, such radially-outwardly biased protuberance on the respective actuation member 25% 25”, 25'” and 25””, etc remains lockingly engaged with the interior circumferential groove or profile 22 on the slidable sleeve 18, and the respective actuation member is thereby prevented from further movement within sliding sleeve 18.
  • each of the associated sliding sleeve members sleeve members 18 and the tubular liner 14 at a location proximate each of said frac ports 16 each have mating engagement means which become respectively lockingly engaged when said sliding sleeve members 18 are each respectively moved so as to uncover a corresponding frac port 16.
  • Such mating/locking engagement means may take the form, as shown for example in Fig.s 2A-2E, of toothed ratchets 70 on collet fingers 71 of sliding sleeves 18, which engage respective toothed ratchets 72 on tubular liners 14 in the region of the associated port 16 when the sliding sleeve is moved to its most downhole position uncovering the associated port 16.
  • such mating/locking engagement means may take the form of one or more radially-outwardly based protuberances 80 on collet fingers 71, which matingly engage annular rings 82 on tubular liners 14 in the region of the associated port 16.
  • the actuation member 25 may be provided with a seating surface 60, configured to provide a sealing surface against which said dissolvable or burstable plug member 30 may abut, which sealing surface 60 in combination with the plug member 30, at least for a limited time, prevents pressurized from travelling through the actuation member, at least until the actuation member 25 has opened the port, and the fracking operation been completed through the opened port.
  • Fig. 6 A shows one embodiment of the actuation member 25 of the present invention, immediately prior to insertion downhole in a tubing string 14.
  • the uphole end thereof is provided with a seating surface 60 to allow the seating of a plug member 30 therewithin, namely a dissolvable ball 32.
  • Dissolvable ball 32 may be flowed downhole by fluid pressure , and caused to seat in seating surface 60, thereby preventing, along with o-ring seals 96 located on seating surface 60, any subsequent passage of fluid past actuation member 25 and thereby and causing dissolvable ball 32 and actuation member 25 to be together flowed downhole.
  • the actuation member 25 may have a plug member 30 in the form of a burstable disk (not shown), which, up to a given fluid pressure applied uphole of actuation member 25, resists passage of fluid through bore 17.
  • a short high fluid pressure pulse may be provided to burst the burstable disk (not shown) to thereafter allow flow of fluid, including produced oil, through internal bore of actuation member 25.
  • collet sleeve 33 is provided at the downhole side thereof.
  • Collet sleeve 33 has a series of longitudinal slots 97 therein, to allow resilient flexing of raised protuberances 27a, 27b, and 27c.
  • exterior periphery of collet sleeve 33 possesses a unique profile 27, comprising one or more resiliently- flexible raised protuberances 27a, 27b, and 27c, each of unique widths and spacing relative to similar protuberances on other actuation members 25 used for actuating and uniquely engaging other sliding sleeves 18 located along tubing liner 14.
  • the longitudinal width W1 of raised protuberance 27b may be of a unique and different width W1 which is different that a width W2 of a corresponding raised protuberance 27b on another actuation member 25, to thereby allow each actuation member to selectively engage a corresponding groove 22b of similar unique width within a sliding sleeve 18.
  • a screen support assembly 43 is threadably secured to an uphole end of collet member 33 of actuation member 25.
  • Screen support assembly 43 has mounted on the outer periphery thereof a coil spring 42, which is initially secured on screen support in a compressed state.
  • a ring member 55 allows a guide pin /stop member 92 therein to slidably move in longitundial channel 91 within screen support assembly 43.
  • a cylindrical sand screen 40 is further provided, which circumferentially surrounds screen support assembly 43 and is located thereon between seating surface 60 and ring member 55.
  • Seating surface 60 is initially secured to screen support assembly 43 by shear screws 94 which are threadably inserted and extend into threaded apertures 95 in screen support assembly 43.
  • Means may further be provided to retain seating surface 60 attached to screen support assembly 43 after shear screws 94 have been sheared, to prevent seating member 60 inadvertently being flowed uphole and covering an opened port 16.
  • a gap/space 93 is further provided between the uphole end of screen support assembly 43 and seating surface 60, to allow movement downhole of seating surface member 60 upon application of uphole fluidic pressure when a ball 30 is used as the plug member to thereby allow shearing of shear screws 95.
  • an uphole force exerted by compressed coil spring 42 is then able to cause desired uphole displacement of sand screen member 40, ring member 55, and seating surface 60.
  • Fig. 6B shows actuation member 25 and the position of sand screen member 40 after shear screws 95 have sheared. As may be seen, after shear screws 95 have been sheared (i.e.
  • Figs. 7-11 show successive stages in one method of the present invention, using the configuration of components as described above and shown in Figures 2A-2E, 3A-3E, and Fig. 4A-4E, and Fig 6A.
  • Fig. 7 is an enlarged full cross-sectional view of the tubing liner 14, associated port 16 and sliding sleeve 18.
  • Sliding sleeve 18 in the embodiment shown is comprised of two individual members 18a and 18b, the latter forming a collet sleeve 71 having ratchet 70 thereon.
  • Fig. 7 depicts such components after a first actuating member 25 has been flowed downhole in tubing liner 14 along with a dissolving ball 32 and protuberances 27a, 27b, and 27c thereon have lockingly engages the corresponding mating apertures 22a, 22b, and 22c in sliding sleeve 18 covering such lowermost (most distal) port 16 in the tubing liner.
  • a hardened metal annular ring 99 may further be threadably secured to the inner circumference of sliding sleeve 18 in the region of grooves 22a, 22b, and/or 22c (in this case shown, on the downhole edge of groove 22b), in order to provide a hardened surface to better prevent any inadvertent movement downhole of actuation member 25 upon application of uphole applied fluidic pressure when fracking the formation 10 via the opened port 16. Details as to the configuration of such hardened annular ring member 99 are further disclosed in US Pub 2020/0182015 co-owned with the present invention.
  • Fig. 8 is a view of the tubing liner 14, associated port 16 and sliding sleeve 18 shown in Fig. 7, immediately after uphole fluid pressure exerted on the plug member 30 has caused the shear pins 94 securing the sand screen 40 to the screen support assembly 43 to be sheared and the helical coil spring 42 as a result become further compressed due to downward pressure thereon .
  • shear pins 95 As may be seen in Fig. 8, due to applied uphole fluid pressure, after locking engagement of actuation member 25 with grooves 22a, 22b, and 22c on the desired sliding sleeve 18 shear pins 95 having sheared, further compressingon of helical coil spring 42 . At this juncture in the sequence of the method of the present invention shear pins 37 , due to the applied uphole fluidic pressure, have not as yet been sheared to allow sliding sleeve 18 to be move downhole to uncover port 16.
  • Fig. 9 is a subsequent view of the tubing liner 14, associated port 16 and sliding sleeve shown in Fig. 8, after fluid uphole pressure has now further caused shear pins 37 to become sheared, thereby allowing actuation member 25 engaged with the sliding sleeve 18 to move downhole to fully open the port 16, and the ratchet member 70 on collet sleeve 71 forming part of individual member 18b now engaged ratchet member 72 on the tubing string 14 thereby preventing further return uphole of the sliding sleeve 18 and actuation member 25 engaged thereto;
  • Fig. 10 is a subsequent view of the tubing liner 14, associated port 16 and sliding sleeve 18 shown in Fig. 9, after uphole fluid pressure has further ceased or been substantially reduced, and helical coil spring 42 spring on the actuation member 25 caused the sand screen 40 to be re-located uphole so as to have at least a portion of the sand screen 40 situated substantially underneath and disposed below the opened port 16.
  • Fig. 11 is a subsequent view of the tubing liner 14, associated port 16 and sliding sleeve 18 shown in Fig. 10 after sand 100 has flowed into the opened port 16 but not been allowed, due to the sand screen 40, to flow into the interior bore 15 of the tubing liner 14.
  • Fig. 12 shows a flow diagram of an embodiment of the method 400 of the present invention to frack and complete a well, using the system and apparatus of the present invention, which locates a sand screen 40 at each port 16 immediately after a fracking step at such given port 16 is completed, to prevent ingress of sand 100 into tubular liner 14 and which allows subsequent production from the formation 10 without having to first “trip out” any frac string and insert a production string /tubing liner 14 in order to commence production.
  • Step 401 comprises the initial step of providing a tubular liner, having a hollow interior bore 15 with a plurality of frac ports 16 longitudinally spaced therealong and a corresponding plurality of sliding sleeve members 18 covering each of said frac ports 16, within a wellbore in a hydrocarbon formation 10.
  • Step 402 comprises the step of situating a substantially cylindrical actuation member 25 having a radial ly-outwardly biased protuberance(s) 27 having a unique profile thereon within the tubing liner 14.
  • Step 403 comprises the step of applying a pressurized fluid to an uphole end of the actuation member 25 and causing the actuation member 25 to flow downhole in the tubing liner 14 and causing the radially outwardly-biased protuberance 27 thereron to engage a corresponding unique mating profile 22 possessed by the sliding sleeve member 25.
  • Step 404 comprises the step of continuing to apply pressurized fluid to the actuation member 25 in the tubular liner 14 and causing the sliding sleeve member 14 and actuation member 25 engaged therewith to together move downhole and cause the sliding sleeve 14 to uncover the associated frac port 16.
  • Step 405 comprises the step of injecting a fracking fluid under pressure into the tubular liner 14 and causing the fracking fluid to flow into the hydrocarbon formation 10 via the opened frac port 16.
  • Step 406 comprises the step of ceasing supply of the supply of fracking fluid under pressure, or reduced pressure, so as to allow a spring member 42 on the actuation member 25 to decompress and thereby reposition a sand screen member 40 on the actuation member 25 to a position covering at least a portion of the opened associated frac port 16, such that hydrocarbon flowing from the hydrocarbon formation 10 through the opened frac port 16 into the hollow interior bore 15 of the tubular liner 14 pass through the sand screen member 40.
  • Step 407 comprises the step, if a dissolving plug member 30 is used, providing dissolving fluid to dissolve same, or if a burstable plug 30 is used on the actuation member 25, providing uphole fluid pressure sufficient to burst the burst plug 30, so as to allow flow of oil into the interior bore 15 of the tubing liner 14.
  • Step 408 comprises the step of determining if all ports have been uncovered and fracked. If not, steps 401 -407 are repeated, using another actuation member 25’ having a unique(different) profile is utilized to open a progressively more uphole port 16, and a sand screen 40 installed in the same manner in respect of such additional port 16,

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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)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

L'invention concerne un système et un procédé pour la fracturation d'un gisement d'hydrocarbures. L'invention concerne également un élément d'actionnement, pouvant s'écouler le long d'un tube de production. Une unique partie clavette sur celui-ci est en prise avec un manchon coulissant souhaité recouvrant un orifice associé dans le tube de production L'application d'une pression de fluide de tête de puits amène le manchon coulissant et l'élément d'actionnement à se déplacer de façon à découvrir l'orifice associé. Après fracturation et arrêt de l'alimentation en fluide de fracturation mis sous pression, un ressort comprimé sur l'élément d'actionnement se relâche de façon à repositionner un tamis à sable immédiatement sous l'orifice de façon à empêcher du sable de s'écouler dans le tube de production L'insertion fluide d'éléments d'actionnement "clavetés" supplémentaires permet une ouverture similaire d'orifices de tête de puits successifs supplémentaires et une fracturation dans les régions de tels orifices ouverts supplémentaires, avec un emplacement similaire de tamis à sable à chaque orifice ouvert. Des éléments de bouchon sur chaque élément d'actionnement se dissolvent ensuite ou sont successivement fracturés pour ainsi permettre la production.
PCT/CA2021/050345 2021-03-15 2021-03-15 Système tout-en-un et procédé associé pour la fracturation et la complétion d'un puits qui installe automatiquement des tamis à sable pour une régulation de sable immédiatement après fracturation WO2022192979A1 (fr)

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Publication number Priority date Publication date Assignee Title
CN118029958A (zh) * 2024-03-14 2024-05-14 西南石油大学 无限级防砂压裂滑套

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US20030141060A1 (en) * 2002-01-25 2003-07-31 Hailey Travis T. Sand control screen assembly and treatment method using the same
US20140083714A1 (en) * 2012-09-26 2014-03-27 Halliburton Energy Services, Inc. Single Trip Multi-Zone Completion Systems and Methods
US20150136392A1 (en) * 2013-11-20 2015-05-21 Baker Hughes Incorporated Multi-zone Intelligent and Interventionless Single Trip Completion
CA2904470A1 (fr) * 2015-04-27 2015-11-18 David Nordheimer Dispositif servant a decouvrir successivement des orifices le long d'un puits de forage pour permettre l'injection d'un fluide le long dudit puits de forage
WO2018201217A1 (fr) * 2017-05-05 2018-11-08 Sc Asset Corporation Système et procédés associés de fracturation et de complétion d'un puits qui installe de manière fluide des tamis à sable pour contrôle du sable
WO2019151993A1 (fr) * 2018-01-30 2019-08-08 Halliburton Energy Services, Inc. Déplacement automatique de manchons de fracturation

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030141060A1 (en) * 2002-01-25 2003-07-31 Hailey Travis T. Sand control screen assembly and treatment method using the same
US20140083714A1 (en) * 2012-09-26 2014-03-27 Halliburton Energy Services, Inc. Single Trip Multi-Zone Completion Systems and Methods
US20150136392A1 (en) * 2013-11-20 2015-05-21 Baker Hughes Incorporated Multi-zone Intelligent and Interventionless Single Trip Completion
CA2904470A1 (fr) * 2015-04-27 2015-11-18 David Nordheimer Dispositif servant a decouvrir successivement des orifices le long d'un puits de forage pour permettre l'injection d'un fluide le long dudit puits de forage
WO2018201217A1 (fr) * 2017-05-05 2018-11-08 Sc Asset Corporation Système et procédés associés de fracturation et de complétion d'un puits qui installe de manière fluide des tamis à sable pour contrôle du sable
WO2019151993A1 (fr) * 2018-01-30 2019-08-08 Halliburton Energy Services, Inc. Déplacement automatique de manchons de fracturation

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN118029958A (zh) * 2024-03-14 2024-05-14 西南石油大学 无限级防砂压裂滑套

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