All-in-one system and related method for fracking and completing a well which automatically installs sand screens for sand control immediately after fracking

Abstract

A system and method for fracking a hydrocarbon formation. An actuating member, flowable along a production string, is provided. A unique key portion thereon engages a desired sliding sleeve covering an associated port in the production string. Applying uphole fluid pressure causes the sliding sleeve and actuating member to move so as to uncover the associated port. After fracking and cessation of supply of pressurized fracturing fluid, a compressed spring on the actuating member decompresses so as to reposition a sand screen immediately beneath the port so as to prevent sand from flowing into the production string. Flowable insertion of additional “keyed” actuating members allows similar opening of additional successive uphole ports and fracking in the regions of such additional opened ports, with similar location of sand screens at each opened port. Plug members on each actuating member thereafter dissolve or are successively burst to thereby allow production.

Claims

1. A system for fracking a hydrocarbon formation at a given location along a wellbore which immediately thereafter installs a sand screen at said location without having to trip out a frac string prior to commencing production, comprising; (a) a tubular liner insertable within said wellbore, said tubular liner having an interior bore and further comprising: (i) a plurality of longitudinally spaced-apart frac ports, spaced at longitudinal intervals along said tubular liner, providing, when open, fluid communication between the interior bore of the tubular liner and an exterior of the tubular liner; (ii) a plurality of cylindrical hollow sliding sleeve members within said interior bore, each configured when in an initial closed position to cover a corresponding of said longitudinally spaced-apart frac ports at each spaced interval along said tubular liner and prevent flow of fluid through said frac ports, each slidably moveable longitudinally in the interior bore to an open position to uncover a corresponding of the frac ports, each of the sliding sleeve members having an interior circumferential groove of a unique profile or of a unique longitudinal width; and (iii) a plurality of shear members, initially securing respectively said plurality of slidable sleeve members to the tubular liner in said initial closed position, and shareable when a longitudinal force is applied to thereafter allow longitudinal slidable movement of respective of said slidable sleeve members; (b) at least one hollow cylindrical actuation member insertable within said tubular liner, comprising: (i) an elongate 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; (ii) 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; (iii) a longitudinally-extending sand screen member, longitudinally slidably moveable along said cylindrical actuation member and of a longitudinal length sufficient to cover said frac port when slidably positioned beneath said frac port, adapted to prevent ingress of sand but permit ingress of oil into a hollow interior of said cylindrical actuation member; (iv) 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 and slidably moves said sand screen member longitudinally within said tubular liner to a location beneath and covering at least a portion of said opened frac port.

2. The system for fracking a hydrocarbon formation as claimed in claim 1, wherein each of said sliding sleeve members and said tubular liner at a location proximate each of said frac ports, have mating engagement means which become respectively lockingly engaged when said sliding sleeve members are each respectively moved so as to uncover a corresponding frac port, which mating engagement means retains said sliding sleeve members, once in said open position, from thereafter returning to a closed position covering said corresponding frac port.

3. The system for fracking a hydrocarbon formation as claimed in claim 2, wherein the mating engagement means on said sliding sleeve members comprises a plurality of collet fingers, radially outwardly biased, and extending from a downhole end of each sliding sleeve member, and said mating engagement means on said tubular liner comprises an annular circumferential ring on said tubular liner, which when one of said slibable sleeve members travels to said open position, said collet fingers thereof matingly engage said annular circumferential ring on said sliding sleeve member.

4. The system for fracking a hydrocarbon formation as claimed in claim 1, wherein: said profile of said radially-outwardly biased protuberance on said actuation member is of a width W1; and said interior circumferential groove on said one sliding sleeve member is of a width equal to or greater than W1.

5. The system for fracking a hydrocarbon formation as claimed in claim 4, further comprising: (c) a second actuation member, insertable within the interior bore of the tubular liner, comprising: (i) an elongate cylindrical hollow collet sleeve, having a radially-outwardly biased protuberance on a periphery thereof having a second unique profile of width W2 where W2<W1, said radially-outwardly biased protuberance configured to matingly engage said interior circumferential groove or profile on another of the plurality of sliding sleeve members having a width equal to or greater than W2 but less than W1; (ii) 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 second actuation member to be forcibly flowed downhole in said tubular liner by said pressurized fluid; (iii) a longitudinally-extending sand screen member, longitudinally slidably moveable along said cylindrical actuation member and of a longitudinal length sufficient to cover said frac port when slidably positioned beneath said frac port, adapted to prevent ingress of sand but permit ingress of oil into a hollow interior of said cylindrical actuation member; (iv) 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 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 along said actuation member in a region 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 and slidably moves said sand screen member longitudinally within said tubular liner to a location beneath and covering at least a portion of said opened frac port.

6. The system for fracking a hydrocarbon formation as claimed in claim 1, wherein: said radially-outwardly biased protuberance on said actuation member is configured such that after matingly engaging said interior circumferential groove or profile on at least one of the plurality of sliding sleeve members, such radially-outwardly biased protuberance on said actuation member remains lockingly engaged with said interior circumferential groove or profile on said slidable sleeve and said actuation member is thereby prevented from further movement within said tubular liner.

7. The system for fracking a hydrocarbon formation as claimed in claim 1 wherein said dissolvable or burstable plug member is a dissolvable plug member which is dissolvable upon a dissolving fluid being applied to said interior bore of said tubular liner.

8. The system for fracking a hydrocarbon formation as claimed in claim 7, wherein said dissolvable plug member is a dissolvable ball which may be flowed downhole in said tubular liner.

9. The system for fracking a hydrocarbon formation as claimed in claim 1 wherein said 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 from travelling through said actuation member.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) Further advantages and permutations and combinations of the invention will now appear from the above and from the following detailed description of various particular embodiments of the invention, taken together with the accompanying drawings each of which are intended to be non-limiting, in which:

(2) 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;

(3) 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;

(4) 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 ‘r’ 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;

(5) 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. 2A, 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;

(6) FIGS. 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;

(7) 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;

(8) 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;

(9) 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 FIGS. 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;

(10) 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);

(11) 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;

(12) 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;

(13) 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

(14) 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.

DETAILED DESCRIPTION OF SOME PREFERRED EMBODIMENTS

(15) 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.

(16) 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, 2A, 3A, and FIG. 4A. 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.

(17) As best seen for example in FIG. 2A and FIG. 4A, 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).

(18) As best seen for example in FIG. 7, 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.

(19) 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 18sa, 18b, the purpose of such internal grooves 22 (ie. 22a, 22b, and 22c) being more fully explained herein.

(20) As more fully explained below and with reference to applicant's corresponding U.S. Pat. No. 10,563,482 entitled “Profile-Selective Sleeve for Multi-stage Valve Actuation” which is incorporated by reference in its entirety with respect to the manner of using profile selective sleeves and their manner of selective engagement by unique actuation members, by providing sliding sleeves 18 each with an interior circumferential groove or grooves 22 of a unique “key” profile (in this case each groove 22 or series of grooves for example 22a, 22b, & 22c, being of a varying width W.sub.1 and a varying longitudinal distance between each groove 22—see for example FIG. 2B and FIG. 4A as well as FIGS. 7-10) and further providing similarly uniquely-keyed actuation members 25 having a similar unique mating profile in the form of a radially-outwardly biased protuberance 27 or protuberances 27a, 27b, 27c on a collet member 33, each of similar varying width and a varying longitudinal distance between each protuberance 27 (ref. for example FIG. 2B, FIG. 4B and FIG. 7 herein), the uniquely-“keyed” actuating member 25 having protuberances 27a, 27b, 27c will selectively matingly engage and only engage with a similar uniquely-“keyed” sliding sleeve 18, having similar sized and spaced internal grooves 22a, 22b, and 22e therein.

(21) After “keyed” engagement of the protuberances 27a, 27b, and 27c of the actuation member 25 with a selected sliding sleeve 18 having therein correspondingly sized and spaced internal grooves 22a, 22b, and 22c and upon application of uphole fluidic pressure to actuation member 25, the particular desired sliding sleeve 18 and actuation member 25 are together caused to be slidably repositioned downhole to thereby uncover and thereby open the associated frac port 16.

(22) As seen for example in FIG. 2A & FIG. 7, 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.

(23) 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 FIGS. 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 FIGS. 3B & 3C, applies a pressure on the actuation member 25, and thus on the sliding sleeve 14 to which it is lockingly engaged.

(24) As referenced above, at least one actuation member 25 is provided, as can best be seen in FIGS. 4B, 4C, & 4D, as well as FIGS. 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. As may be best seen from FIGS. 6A & 6B, as well as from FIGS. 7, 8, 9 & 10, 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.

(25) A plug member 30, which may be a dissolvable plug member 32 such as a dissolvable ball, or alternatively a burstable 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;

(26) As regards collet sleeve portion 33 of actuation member 25, such collet sleeve portion 33 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. 4C-4E, to allow mating engagement (preferably locking engagement, as more fully set out herein) with a corresponding sliding sleeve 18 having a similar unique profile. Thereafter, fluid pressure exerted in tubing liner 14 on an uphole side of actuation member 25 causes both the actuation member and mated sliding sleeve 18 to be forced downhole, thereby opening respective port 16.

(27) As regards a dissolvable or burstable plug member 30, such plug member 30 (for a limited time in the case of a dissolvable plug, or up to a specified pressure in the case of a burstable plug member) 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.

(28) After the supply of a dissolvable fluid which acts on the plug member 30 to cause it after a period of time to dissolve, or where the plug member 30 is a burstable plug (not shown), after the provision of a pressure pulse uphole of the burstable plug causing it to burst, oil which enters interior bore 15 of tubular liner 14 may be freely pumped uphole.

(29) As regards longitudinally-extending sand screen member 40 forming part of actuating member 25, such sand screen member 40 as best seen in FIGS. 4B-4E, 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.

(30) As may be best seen from FIGS. 4B-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.

(31) As regards spring member 42 forming part of actuating member 25, spring member 42 is in a preferred embodiment a helical coil spring, as best shown in FIGS. 4B-4E. Coil spring 42 may be positioned over/around a collet member 43, and is slidably moverable along collet 43 to permit its compression and decompression. 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.

(32) 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 FIGS. 2E, 3E, & 4E.

(33) As noted above, 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. In a preferred embodiment, and as best seen in FIGS. 2A-2C, 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. 2C), 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.

(34) As best shown in FIGS. 5A-5E, the mating engagement means on the sliding sleeve members 14 may alternatively comprise a plurality of collet fingers 71 having protuberances 80 thereon (in place of toothed ratchets 70) which are radially outwardly biased, and extending from a downhole end of each sliding sleeve member 18. 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 FIGS. 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.

(35) In the embodiments shown and as best seen in FIG. 4D, 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 W1, and the corresponding interior circumferential groove 22 on sliding sleeve member 18 is of a width equal to or greater than W1, as shown, to thereby permit mating engagement therebetween. However, where additional actuation members 25 are employed to open additional successively-more-uphole sliding sleeves 18 covering other additional corresponding uphole ports 16 along tubular liner 14, the width of each protuberance 27b on each successively employed actuation member 25, namely widths W2, W3, W4, will each be less than width W1, 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.

(36) This configuration, whereby the width of the protuberance 27b on successive actuation members 25 and the width of annular grooves 22 on the tubular liner 14 in the region of progressively more uphole ports successively lessens thus ensures that successively-inserted actuation members 25, each with successively lesser widths of protuberance 27b, will successively engage and open each of progressively more uphole sliding sleeves 14.

(37) Thus in a further refinement of the present invention, 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.

(38) Again, in such an embodiment, for each successive actuation member 25′, 25″, 25′″ and 25″″, etc., 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.

(39) Similarly, for 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.

(40) Such mating/locking engagement means may take the form, as shown for example in FIGS. 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. Alternatively, as shown in FIGS. 5A-5E, 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.

(41) In one embodiment, where the plug member is dissolvable ball 32, and as best seen in FIGS. 2E, 3E, and 5E, 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.

(42) FIG. 6A shows one embodiment of the actuation member 25 of the present invention, immediately prior to insertion downhole in a tubing string 14.

(43) In the embodiment shown (ie. immediately prior to being provided with an additional plug member 30 and being flowed downhole), 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.

(44) Alternatively, in place of seating surface 60 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.

(45) Upon uphole fluid pressure exceeding a certain pressure, for example immediately subsequent to supplying pressurized fracking fluid through ports 16, 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.

(46) On actuation member 25 a 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.

(47) Specifically, 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. For example, 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.

(48) 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 longitudinal channel 91 within screen support assembly 43.

(49) 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 (not shown) 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.

(50) 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. Upon 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.

(51) 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. after application of a high pressure pulse of fluid to an uphole end of actuation member 25 when the later is engaged with a corresponding sliding sleeve 18 each have together moved downhole to uncover a corresponding port 16, and after fracking of the formation through the opened port 16), the restriction posed by shear screws 95 in preventing compressed coil spring 42 from forcing sand screen, seating surface 60, and ring member 55 is thereby removed. Accordingly, coil spring 42 decompresses and in doing so longitudinally extends so as to force sand screen 40 longitudinally uphole, to the position shown in FIG. 6B. Gap 93 between seating surface 60 and screen support assembly 43 is now significantly greater, as shown in FIG. 6B compared to FIG. 6A.

(52) FIGS. 7-11 show successive stages in one method of the present invention, using the configuration of components as described above and shown in FIGS. 2A-2E, 3A-3E, and FIG. 4A-4E, and FIG. 6A.

(53) Specifically, 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.

(54) As may be best seen in FIG. 7, in order to assist in ensuring locking engagement of radial protuberances 27a, 27b, 27c on collet portion 33 of actuation member 25 with internal corresponding mating grooves 22a, 22b, and 22c on selected sliding sleeve 18, 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.

(55) 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.

(56) 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 compressing on 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.

(57) 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;

(58) 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.

(59) 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. and

(60) Operation of the Invention

(61) 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.

(62) 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.

(63) Step 402 comprises the step of situating a substantially cylindrical actuation member 25 having a radially-outwardly biased protuberance(s) 27 having a unique profile thereon within the tubing liner 14.

(64) 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 thereon to engage a corresponding unique mating profile 22 possessed by the sliding sleeve member 25.

(65) 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.

(66) 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.

(67) 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.

(68) 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.

(69) 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.

(70) If all ports 16 have been uncovered and fracked, and sand screens 40 inserted at each successively opened port 16, then as recited in step 409, oil is thereafter produced from the completed wellbore 12.

(71) Other permutations and combinations of the above steps in the above method will now occur to persons of skill in the art, and are contemplated herein.

(72) The foregoing description of the disclosed embodiments of the system and methods of the present invention are provided to enable any person skilled in the art to make or use the present invention. The scope of the claims should not be limited by the preferred embodiments set forth in the examples, but should be given the broadest interpretation consistent with the specification, including the description and drawings, as a whole. Thus, the present invention is not intended to be limited to the embodiments shown herein, but is to be accorded the full scope consistent with the claims.

(73) For a complete definition of the invention and its intended scope, reference is to be made to the summary of the invention and the appended claims read together with and considered with the disclosure and drawings herein.