Patent Grant
11713638
The present invention relates to a baffle system and method for fracturing or treating a hydrocarbon formation. More particularly, the present invention relates to a baffle system where one or all of the baffles employed during fracking are retrievable from a well casing.
This background and patent documents identified below are provided for the purpose of making known information believed by the applicant to be of possible relevance to the present invention, and in particular allowing the reader to understand advantages of the invention over devices and methods known to the inventor, but not necessarily public. No admission is necessarily intended, nor should be construed as admitting, that any of the following documents or methods known to the inventor constitute legally citable and relevant prior art against the present invention.
Preferably when fracking a wellbore it is usually necessary, for optimization of pressurized and to concentrate volumes of fluid in localized areas, particular zones along the wellbore are opened to the formation to allow fracking of the formation in such area while isolating (i.e. closing off) all other zones along the well casing during such localized fluid injection. Such typically results in having to isolate, by means of packers or plug members pumped downhole, certain segments of the wellbore which may be otherwise open to the formation. Alternatively, where the well casing possesses slidable sleeves which are typically closed during insertion of and cementing of the casing in the wellbore, only select slidable sleeves along the well liner are opened, to thus allow introduction of high pressure fluid only into a targeted zone of the formation along the wellbore while still maintaining all sleeves in unfracked areas along the well casing closed.
Each of the foregoing scenarios results in actuation means such as sleeves, balls, packers, or the like being provided down the well to achieve in some manner the desired isolation to achieve fracking of a specific region of the formation.
Often such equipment or tools, while often annular and having a flow-though passage, are permanently left in the well, thereby substantially restricting to some degree the flow of produced hydrocarbons through the well casing due to resulting reduced diameter of the wellbore.
Alternatively, difficult and expensive reaming operations need to be conducted to ream out any remaining plug members or actuation sleeves used in the fracking process to thereby maintain full production diameter of the wellbore when the wellbore goes to production.
Certain published documents teach, with varying degrees of success and complexity, various equipment and methods for isolating segments of the wellbore for fracking purposes while attempting to maintain, after fracking, as unrestricted a flow passage from the well casing as possible.
For example, CA 2,879,044 entitled “System and Method for Injecting Fluid at Selected Locations Along a Wellbore” teaches a system and method for selectively actuating (moving from closed position to open position) a plurality of sliding sleeves in a tubing liner, which are covering ports in the tubing liner, via one or more darts inserted into the wellbore to allow fracking of the wellbore in the regions of the opened ports. The actuating dart is preferably coupled to a retrieval tool (or is coupleable to a retrieving tool) which upon the retrieval tool being so coupled allows a bypass valve to be opened to thereby assist in withdrawing the dart from within the valve sub-members. Upward movement of the retrieval tool allows a wedge-shaped member to disengage the dart member from a corresponding actuated sleeve to allow the dart and retrieving tool to be withdrawn from the wellbore. The sliding sleeve nevertheless remains in the well liner.
As is apparent from the above, the invention of CA 2,879,044 is directed to tubing liners/well casing having pre-existing sliding sleeve members therein covering ports in the tubing liner. As such, this invention is directed to, and only utilizable with, tubing liners of such (pre-existing) configuration, and accordingly is not directed to nor utilizable in well casings which do not possess pre-existing sliding sleeves covering pre-existing ports in such tubing liners.
CA 2,904,470 entitled “System for Successively Uncovering Ports along a Wellbore to Permit Injection of a Fluid along said Wellbore” having a common inventor with the present invention, teaches a system for moving sleeves to successively uncover a plurality of contiguous ports in a tubing liner within a wellbore which are covered by such sleeves, or for successively uncovering individual groups of ports arranged at different locations along the liner, to allow successive fracking of the wellbore at such locations. Sliding sleeves in the tubing liner are successively moved from a closed position covering a respective port to an open position uncovering such port by an actuation member placed in the bore of the tubing liner and pumped down the tubing liner. The actuation member for moving the sliding sleeves to cause them to open comprises a single collet sleeve, having a dissolvable plug retained in a fixed position within such collet sleeve by shear pins. The collet sleeve has radially-outwardly biased protuberances (fingers) at a downhole end thereof, adapted to and which matingly engage corresponding cylindrical grooves in such sliding sleeves, based on the width of the protuberance. Upon the actuation member actuating all of the desired sleeves and after having actuated the last most downhole sleeve, the shear pin shears thereby allowing the plug in the collet to move downhole in the collet sleeve and thereby preventing the protuberances (fingers) on the collet sleeve from thereafter disengaging the cylindrical groove of the corresponding sliding sleeve, thereby preventing any further progress of the collet sleeve downhole.
Again as will be apparent, such invention like the invention disclosed in CA 2,879,044 is directed to tubing liners/well casing having pre-existing sliding sleeve members therein covering ports in the tubing liner. As such, this invention is directed to, and only utilizable with, tubing liners of such (pre-existing) configuration, and accordingly is not directed to nor utilizable in well casing which does not possess pre-existing sliding sleeves covering pre-existing ports in such tubing liner.
U.S. Pat. No. 5,398,763 entitled “Wireline Set Baffle and Method of Setting Thereof”, in contrast to the above two patent publications, teaches a setting tool which may be used to position a baffle within a well casing, which baffle may then act as a seat for a plug member which is then inserted downhole to isolate downhole sections, and thereby allow such regions of the casing above the baffle which are perforated to be fracked. To such extent U.S. Pat. No. 5,398,763 have a number of similarities with the present invention.
However, the apparatus and method of U.S. Pat. No. 5,398,763 has a number of important differences with the system and method of the present invention, not the least of which, in respect of the second, third, and fourth embodiments thereof, is the need for explosive charges to shear shear pins or the need of actuating blasting cap on the setting tool, which adds to the complexity and expense of a setting tool.
Despite the above prior art teachings, a need still exists in the fracking industry for a simple system and method for effectively isolating certain sectors of a wellbore for fracking, which after completion of the fracking along a length of a wellbore nonetheless leaves the length of the wellbore virtually unrestricted and of maximum original diameter to maximize flow of hydrocarbons therethough during production.
It is further advantageous if such a system and method can further at the same time provide accurate perforation of the well casing, to minimize errors in depth placement of the perforations along the wellbore and to minimize the number of tripping in and out of the wellbore of various equipment if perforation and fracking operations were otherwise independently conducted, to speeding up perforating and fracking operations in completing wells for production.
It is thus an object of the present invention to provide a relatively simple system and method for fracking which allows the desired isolation of particular successive segments along a wellbore, yet nonetheless after completion of fracking leaves the wellbore virtually unrestricted and of maximum original diameter to increase flow during production.
It is a further object of certain embodiments of the present invention to provide a baffle member which may be uniquely engaged with a landing sub at a known depth along the wellbore, which temporarily effectively prevents flow of pressurized fracking fluids downhole but which baffle member may after completion of perforation and fracking operations be easily removed from the well casing leaving the well casing unrestricted.
It is a further object of certain embodiments of the present invention to provide a method for fracking a formation, which after such operation leaves the wellbore virtually unrestricted and of maximum original diameter to increase flow during production.
Accordingly, in order to overcome some of the disadvantages of the prior art designs and/or in order to further realize one or more of the above non-limiting objects of the present invention, the collet baffle system and method of the present invention generally comprises a number of components, having:
The landing subs are deployed in the casing install on desired depth and spacing. Each landing sub, in one embodiment of the invention, has its own unique landing length for the matching collet finger protuberances on a particular baffle member. For example, the landing sub at the toe of the wellbore will have the longest profile, with each consecutive profile/annular recess in each landing sub being of a reduced length progressing from heel to toe (in a deviated well) or from the base of the well upwards in a vertical well.
Landing subs can be run in to the wellbore with a desired spacing, which may be every 30 meters, for example, or some other unique configuration tailored to the geology of the formation. After the casing has been installed and cemented into place the wireline (or coiled tubing) and frac equipment will rig up. The baffle member is frangibly affixed to a standard conveying tool, such as Baker Style #20 setting tool, such as by a shear pin of a selected/desired shearing force. The conveying tool may further be provided with perforating guns, to allow precise location of the perforations in the well casing relative to each landing sub.
The assembly (baffle member, conveying tool, and perforating guns) may then be conveyed downhole via wireline or coiled tubing. Once the baffle member forming part of the aforementioned assembly has reached its target landing sub and the annular recess therein, the collet finger protuberances on the baffle member expand radially outwardly to matingly engage the target landing sub, thereby preventing the baffle member from any further downhole movement. Circumferential external seals on the baffle member provide a seal against the landing sub. The conveying tool is now forceably pulled uphole, causing the shear pins to shear allowing the conveying tool to disengage from the baffle member and leaving the baffle member engaged with the target landing sub. The conveying tool and perforating guns are now moved (if desired) to a desired perforating depth above the landing sub, and the perforating guns activated. The perforating guns and conveying tool are then pulled to surface. A plug member, such as a dissolvable ball, it then pumped or flowed downhole with fracturing fluid. The ball lands on a ball seat on the baffle member, and creates a seal. The fracture fluid is then pumped into the formation via the perforations created in the well casing at the desired depth.
The aforementioned process may be repeated, albeit with a second baffle member having collet finger protuberances of a different (lesser) width or spacing than those employed on the first baffle member, to allow earlier engagement of a landing sub immediately uphole from the lowermost landing sub.
The first baffle member, prior to landing of additional baffle members in corresponding landing subs, may be removed by means of a retrieving tool. Typically, however, the baffle members are left in the wellbore until after perforation and fracking. After completion of perforating and fracking of the formation, the balls seated therein dissolve. Prior to initiation of production the baffle members can all be simultaneously retrieved by running a retrieving tool to the toe of the well, activating dogs on the retrieving tool, and pulling the retrieving tool uphole—the chamfer on the uphole side of the recesses in the landing subs and/or a chamfer on the uphole side of the collet finger protuberances allows release of each of the baffle members from mating engagement with their respective landing subs. The recovery of the baffle members to surface advantageously allows for dramatically increased inner diameter of the well casing for increased flow back and production.
More particularly, in a first broad embodiment of the present invention, the invention comprises a baffle system for use in a well casing having a plurality of landed subs longitudinally spaced therealong, for progressively fracking or treating fluid into a hydrocarbon formation via existing or created perforations in said well casing, said system comprising:
In a preferred embodiment, the frangible means comprise shear pins or shear screws which affix the conveying tool, at a lower region thereof, to an upper portion of the baffle member. The conveying tool is preferably frangibly affixed to the baffle member uphole of the collet finger protuberances thereon.
In a further preferred embodiment, the baffle member, at an uppermost portion about an interior peripheral mouth thereof, has a chamfer to allow radially-outwardly biased dogs on a retrieving tool inserted therein to be radially compressed and thereby allow said retrieving tool to pass therethrough; and at a lowermost portion has a shoulder to allow said radially-outwardly biased dogs after having passed through said baffle member to abut said dogs and allow said retrieving tool, when pulled uphole, to thus pull said baffle member uphole.
The baffle system in preferred embodiments is provided with a plurality of annular recesses respectively situated within a corresponding plurality of said landing subs, longitudinally spaced apart from each other along said well casing, a most downhole of said plurality of annular recesses having the greatest annular width, with remaining uphole annular recesses having, when progressing uphole along said well casing, progressively narrower widths.
The conveying tool, and in particular a conveying head thereof, is preferably provided with an electrically-actuated explosive charge for perforating said well casing.
Preferentially, each landing sub has a respective annular recess therein, wherein a respective annular baffle member when matingly engaged within a landing subs thereby positions said explosive charge immediately above said respective landing subs, so that said explosive charge, when detonated, perforates the well casing immediately above the desired landing sub.
In one embodiment the radially outwardly-biased collet finger protuberances are situated approximately midpoint on said baffle member, intermediate annular seals situated on an outer periphery of said baffle member at mutually opposite ends thereof. The collet finger protuberances may alternatively, if desired, simply be situated at a distal (downhole) end of the baffle member, and not midpoint thereof.
Preferentially, the conveying tool has a bypass port therein to allow fluid to flow therethrough when lowering said conveying tool within said well casing.
In another broad aspect of the present invention, the present invention comprises a method for fracking or treating a hydrocarbon formation having a well casing located therein and having a plurality of landing subs spaced along said well casing, commencing with the most distal regions of said well casing and progressing uphole along said well casing until all regions of said hydrocarbon formation have been fracked or treated, comprising the steps of:
In an alternative embodiment, such method comprises the steps of:
(ii) affixing to a most downhole end of a conveying tool, via frangible means, a first baffle member having outwardly-biased collet finger protuberances thereon of a spacing adapted to matingly engage said annular recesses in a lowermost of said landing subs;
(iii) Inserting said conveying tool and baffle member downhole in said well casing until said collet finger protuberances engage said annular recesses in a lowermost of said landing subs;
(iv) pulling uphole on said conveying tool and causing said frangible means thereon to shear thereby releasing said baffle member from said conveying tool;
(v) withdrawing said conveying tool from said well casing;
In a preferred embodiment of the above two methods, the annular recesses, on an uphole side edge thereof and/or said collet finger protuberances, on an uphole side thereof, have a chamfered portion to allow withdrawal of finger protuberances therewith.
In one refinement of the above methods, after step (viii) the following steps may be inserted, namely:
In another alternatively refinement of the above methods, after step (ix) the following steps may be added, namely:
In a further refinement of the above method, such method further comprises the step, after step (iii) and after said annular baffle member has matingly engaged within a lowermost of said landing subs, of:
igniting an explosive charge on said conveying tool immediately above said lowermost of said plurality of landing subs, and detonating said explosive charge so as to perforate the well casing immediately above said lowermost landing sub.
The above summary of the invention does not necessarily describe all features of the invention. For a complete description of the invention, reference is to further be had to the drawings and the detailed description of some preferred embodiments, read together with the claims.
Further advantages and other embodiments of the invention will now appear from the above along with the following detailed description of the various particular embodiments of the invention, taken together with the accompanying drawings each of which are intended to be non-limiting, in which:
In the following description, similar components in the various drawings are identified with corresponding same reference numerals.
Reference to an element in the singular, such as by use of the article “a” or “an” is not intended to mean “one and only one” unless specifically so stated, but rather “one or more”.
Reference to the relative terms “upper”, “uppermost”, “above”, “below”, “lowermost”, or “bottom” are with reference to the position of a component within a vertical well casing.
“Downhole” consistently means toward the end of the well or well casing, regardless as to whether such well or well casing is vertical, or is horizontal or deviated as occurs in deviated wells.
In the drawings, the following convention is adopted, namely downhole within a wellbore or well casing is toward the bottom of the page for portrait-style figures, and to the right of the page for landscape-style figures.
Specifically,
Pre-existing perforations (not shown) may be provided in well casing 12, but preferentially are created in well casing 12 in the manner described herein, immediately prior to fracking a zone of the formation along the well casing.
As may be seen, landing subs 14a, 14b threadably coupled at together 18 via standard threaded couplings to form an integral well casing 12, are provided at spaced locations along well casing 12, each landing sub 14a, 14b have at least one annular recess 16 therein. The annular recess 16′ in the lowermost of landing subs 14a is of the greatest length (width) “a”, and successively more uphole landing subs, such as landing sub 14b, have a corresponding annular recesses 16″ therein of a progressively lesser width “b”, as shown in
Importantly, each annular recess 16, on a downhole side edge thereof, is provided with a shoulder 17, which prevents further downhole movement of a baffle member 30 once said baffle member has become matingly engaged, in the manner set out below, with a respective annular recess 16. In a preferred embodiment shoulder 17 on each is “back-milled”, and similarly matingly engages shoulder 53 on baffle member 30 which is similarly “back milled, as best shown in
In order to commence a fracking operation, as seen from
In the embodiment shown in
As seen from
As noted above, conveying head 22 is frangibly secured at a lower end thereof to an upper interior portion 32 of baffle member 30. Such securement (coupling) of baffle member 30 to conveying head 22 of conveying tool 20 is a frangible connection, via shear screws 26. Other means of frangibly securing baffle member 30 to conveying head 22 will now occur to persons of skill of the art, such as using tack welding forming a breakable/shearable weld joint, or by friction-fit shear pins (not shown) which are shearable, and each of said alternative frangible means are expressly contemplated within the scope of the invention.
Baffle member 30, as best seen from the various embodiments thereof in
Baffle member 30 is provided with a plurality of radially outwardly-biased collet finger protuberances 50, which are preferentially located at a midpoint of baffle member 30 (see
Specifically, baffle member 30 shown in
Baffle member 30′ shown in
Each of radially outwardly-biased collet finger protuberances 50, 50a, 50b, 50c, 50d on all baffle members 30, 30′, 30″, and 30″′ may possess a chamfer 70 at an uphole side edge thereof. Alternatively, or in addition, each annular recess 16′, 16″, etc. may likewise possess a similar chamfer 72 at an uphole side edge thereof.
The purpose of chamfers 70 and/or 72 on uphole side edges of protuberances 50, 50a, 50b, 50c, 50d and/or annular recesses 16, 16′ respectively is so that upon an upward (i.e. uphole) force applied to a lowermost end of a baffle member 30, 30′, 30″, 30″′ (by a retrieval tool 90 has hereinafter described) such will cause the uphole side edge of collet finger protuberances 50, 50a, 50b, 50c, 50d thereon to “ride up” on the uphole (chamfered) side edge 72 of the respective annular recess(es) 16, 16′, engaged by the respective collet finger protuberance 50, 50a, 50b, 50c, 50d, and thereby cause collet finger protuberances 50, 50a, 50b, 50c, 50d to be radially inwardly compressed and thus become disengaged from mating engagement with the respective annular recesses 16, 16′, and 16″, so as to allow a respective baffle member 30, 30′, 30″, 30″′ to be then withdrawn from the respective landing sub 14a, 14b and further withdrawn from well casing 12.
Each of collet finger protuberances 50, 50a, 50b, 50c, 50d, on a downhole side edge thereof preferably possess a shoulder 53 which when said protuberances are matingly engaged with a respective annular recess 16′, 16″, prevents further downhole movement of baffle member 30 within well casing 12.
Baffle member 30, at an uppermost portion thereof about an interior peripheral mouth 34 thereof has an inward chamfer 100. Inward chamber 100 on baffle member 30 allows radial-outwardly extending dogs 92 on a retrieving tool 90 (see
A lowermost portion of baffle member 30 is provided with a shoulder 39 which allows said radially-outwardly extending dogs 92, after having passed downhole through baffle member 30 and when then allowed to be radially outwardly extended, to abut shoulder 39 to allow retrieving tool 90 when pulled uphole to additionally pull baffle member 30 uphole also, as shown sequentially in
Such shoulder 39 may be bevelled, as shown most clearly for example in
In a preferred embodiment, explosive charge(s) 142 are provided on conveying tool 20, and preferably on a downhole side of conveying head 22 thereof as shown in
In such preferred embodiment, after a baffle member 30 has been lowered and respectively become matingly engaged to an annular recess 16 in a particular landing sub 14, an upward force applied to conveying head 22 via the wireline or coil tubing to which conveying head 22 is coupled shears the shear pins 26 and thereby decouples conveying head 22 from baffle member 30. Thereafter coupling head 22 and explosive charge 140 thereon may together be lifted slightly uphole in well casing 12 to a desired distance above baffle member 30 and corresponding landing sub 14, and explosive charge(s) 140 thereon may be detonated to create perforations 142 in well casing 12 at such desired location(s) along well casing 12.
The conveying tool 20 and detonated explosive charges 140 may then be raised from within well casing 12.
A plug member 40 may then be lowered in well casing 12, which plug member 40 (typically a ball member) then rests on sealing surface 34 on baffle member 30 to thereby isolate zones of the well casing 12 below the landed baffle member 30. If desired, a packer member (not shown) may be lowered downhole and actuated a distance uphole from the ball member 40 to isolate the well casing 12 above the packer. Such packer member is not however necessary, as explained below. Pressurized fracking fluid may then inject in the well casing 12 in the region intermediate the packer member (not shown) and the ball member 40 to thereby frac the formation in such desired location.
In order to achieve certain desired advantages of the invention, the operation of a preferred embodiment and method to selectively and successively perforate and frack a particular zone of a formation, commencing from a most distal end of a well casing 12 in the desired fracking zone, is described below.
Firstly, a plurality of landing subs 14 spaced along a well casing 12 is located in a well drilled within a hydrocarbon formation.
Each of landing subs 14 have one or more annular recesses 16 therein, being of a progressively lesser width progressing uphole from a most distal end of the wellbore, A lowermost landing sub 14 in a zone to be fracked possesses the annular recess 16 of greatest width. Alternatively, each landed sub 14 may possess a plurality of annular recesses 16, of unique but varying widths and/or spacing therebetween, to allow only a single baffle member 30 having similarly-configured collet finger protuberances 50, to uniquely engage same.
A first (initial) baffle member 30 is affixed to a downhole end of conveying tool 20 via frangible means such as shear pins 26. Baffle member 30 has radially-outwardly biased collet finger protuberances 50 thereon, configured to matingly engage only the unique annular recess(es) 16 within a lowermost landing sub 14 of well casing 12 in a zone to be fracked.
Thereafter, the conveying tool 20 and frangibly coupled first baffle member 30 are together lowered downhole in well casing 12 until said collet finger protuberances 50 on baffle member 30 matingly engage annular recess(es) 16 in lowermost landing sub 14a in a zone of such well casing to be fracked.
Thereafter, an uphole force is applied to conveying tool 20 via the wireline or coiled tubing to which conveying tool 20 is coupled, thereby shearing shear pins 26 and de-coupling baffle member 30 from conveying tool 20.
Conveying tool is then raised slightly within well casing 20 to a position immediately above baffle member 30, and an explosive charge 140 on the lowermost portion of coupling head 22 is detonated, thereby creating perforations 142 in well casing 12 immediately above the lowermost landing sub 14.
The conveying tool is then withdrawn from the well casing 12, and a plug member 40 is flowed down well casing 12. Plug member 40 will then be caused to sit in sealing surface 34 on baffle member 30, thereby isolating further downhole portions of the wellbore and causing said plug member 40 to abut an uppermost portion of said baffle member 30 so as to prevent passage of pressurized fluid downhole of baffle member 30.
A packer member on coil tubing may then be inserted downhole, and actuated above perforations 142 to thereby isolate regions of the well casing 12 above the packer, and a pressurized fluid injected in the coil tubing to frac the well casing 12 in the region intermediate the packer and the plug member 40. It is not necessary, however, to utilize a packer member (not shown) to isolate sections of the well casing 12 above baffle member 30, since well casing 12 is not otherwise perforated above created perforations 142 therein and loss of pressurized fluid into other uphole regions of the well casing 12 will not thus occur.
The plug member 40 is then caused to be removed from well casing 12. This is done by plug member 40 preferentially being a dissolvable ball, which then dissolves after being in contact with such pressurized fluid, which fluid is typically acidic or acidic fluid may then be injected downhole to dissolve plug member 40. Alternatively, plug member 40 may merely have been lowered on a wireline, and after completion of the fracking operation may then be pulled to surface.
The aforesaid steps are repeated, in each instance with second and additional baffle members 30. In each iteration, the baffle member 30 has collet finger protuberances 50 thereon of a lesser width, or of a different spacing, which allow respective engagement of progressively more uphole annular recesses 16 in each of the plurality of landing subs 14, until said hydrocarbon formation has been completely fracked or treated.
At the culmination of the fracking operation, a retrieving tool 90 having pressure actuated radially-extending dogs 92 thereon, is lowered downhole below the lowermost of the baffle members 30 matingly engaged within well casing 12 to respective landing subs 14, as shown sequentially in
Retrieving tools 90 having pressure actuated radially-outwardly extending dogs 92 are well known to persons of skill in the art and are readily commercially available. Accordingly, retrieving tool 90, a particularly suitable version for these purposes being shown in
Upon actuation of radially outwardly extending dogs 92 on retrieving tool 90, such dogs 92 engage shoulder 39 on lowermost portion of the lowermost baffle member 30, as shown in
Additional upward force applied to retrieving tool 90 causes similar disengagement of successive uphole baffle members 30 with respective landing subs 14, thereby additionally and advantageously allowing such additional uphole baffle member 30 to be withdrawn from well casing 12 at the same time, and via only a single retrieving tool 90.
Advantageously, well casing 12 has thus had removed therefrom all actuating and isolating tools, thereby retaining its maximum diameter and reducing to the greatest extent possible any flow restrictions in well casing 12. Such elimination of flow restrictions thereby reduces any pressure drops along such well casing 12 and thereby, for a given pumping horsepower, maximizes the amount of hydrocarbons which may then be pumped to surface.
In such manner hydrocarbons entering the created perforations 142 in the well casing 12 are then able to flow in a well casing 12 of maximum diameter, thereby maximizing to the greatest extent the flow of hydrocarbons through the well casing 12 when producing such hydrocarbons to surface.
The above description of some embodiments of the present invention is provided to enable any person skilled in the art to make or use the present invention.
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 detailed description and drawings herein on a purposive interpretation thereof.
| Number | Name | Date | Kind |
|---|---|---|---|
| 47804 | Daniels | May 1865 | A |
| 776523 | Lukins | Dec 1904 | A |
| 1433722 | Hinderliter | Oct 1922 | A |
| 1445581 | Fullop | Feb 1923 | A |
| 2897896 | Kenneday | Aug 1959 | A |
| 2904114 | Webb | Sep 1959 | A |
| 2980185 | Daffin | Apr 1961 | A |
| 4254983 | Harris | Mar 1981 | A |
| 4626134 | Coumont | Dec 1986 | A |
| 5086844 | Mims | Feb 1992 | A |
| 5398760 | George | Mar 1995 | A |
| 5398763 | Watson | Mar 1995 | A |
| 5398764 | Collins | Mar 1995 | A |
| 5538082 | Zwart | Jul 1996 | A |
| 6439313 | Thomeer | Aug 2002 | B1 |
| 7325617 | Murray | Feb 2008 | B2 |
| 7395856 | Murray | Jul 2008 | B2 |
| 7552779 | Murray | Jun 2009 | B2 |
| 8499840 | Bennett | Aug 2013 | B2 |
| 8499844 | Gandikota | Aug 2013 | B2 |
| 8839873 | Johnson | Sep 2014 | B2 |
| 9611727 | Campbell et al. | Apr 2017 | B2 |
| 9739117 | Campbell et al. | Aug 2017 | B2 |
| 11506013 | Nordheimer | Nov 2022 | B2 |
| 20030173089 | Westgard | Sep 2003 | A1 |
| 20050011650 | Harrall | Jan 2005 | A1 |
| 20070221384 | Murray | Sep 2007 | A1 |
| 20090065196 | Holland | Mar 2009 | A1 |
| 20110277989 | Frazier | Nov 2011 | A1 |
| 20120074722 | Beach | Mar 2012 | A1 |
| 20120085539 | Tonnessen | Apr 2012 | A1 |
| 20120168180 | Johnson | Jul 2012 | A1 |
| 20130037255 | Kash | Feb 2013 | A1 |
| 20130081827 | Etzel | Apr 2013 | A1 |
| 20130186647 | Xu | Jul 2013 | A1 |
| 20140246207 | Hofman et al. | Sep 2014 | A1 |
| 20140251612 | Powers | Sep 2014 | A1 |
| 20140345878 | Murphree | Nov 2014 | A1 |
| 20160251923 | Keerthivasan et al. | Sep 2016 | A1 |
| 20170130535 | Helvenston | May 2017 | A1 |
| Number | Date | Country |
|---|---|---|
| 2016413286 | Oct 2021 | AU |
| 2879044 | Mar 2015 | CA |
| 2904470 | Nov 2015 | CA |
| 1714226 | Dec 2005 | CN |
| 102918227 | Feb 2013 | CN |
| 103097653 | May 2013 | CN |
| 204532245 | Aug 2015 | CN |
| 2314415 | Jan 2008 | RU |
| 2415254 | Mar 2011 | RU |
| 2435938 | Dec 2011 | RU |
| 2651865 | Apr 2018 | RU |
| 2683294 | Mar 2019 | RU |
| 2004070162 | Aug 2004 | WO |
| 2014046841 | Mar 2014 | WO |
| Entry |
|---|
| International Search Report issued in PCT/CA2016/050455, dated Sep. 20, 2016, pp. 1-3. |
| Written Opinion issued in PCT/CA2016/050455, dated Sep. 20, 2016, pp. 1-3. |
| Site Oil Tools Ltd. 1981-1982 Wireline Production Equipment Catalogue. |
| Number | Date | Country | |
|---|---|---|---|
| 20200362661 A1 | Nov 2020 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 14991597 | Jan 2016 | US |
| Child | 16945088 | US |
