Not applicable.
This disclosure relates to systems for completing a subterranean wellbore. More particularly, this disclosure relates to systems for injecting gravel into a subterranean wellbore during open hole completion operations.
To obtain hydrocarbons from subterranean formations, wellbores are drilled from the surface to access the hydrocarbon-bearing formation (which may also be referred to herein as a producing zone). After drilling a wellbore to the desired depth, a completion string containing various completion and production devices is installed in the wellbore to produce the hydrocarbons from the producing zone to the surface. In some instances, no casing or liner is installed within the section of the wellbore extending within the producing zone. To prevent the free migration of sands or other fines from the producing zone into the completion and production devices (that is, along with any produced hydrocarbons), a fluid flow restriction device, usually including one or more screens, is placed within the un-cased section of the wellbore, and proppant (which is generally referred to herein as “gravel”) is injected in a slurry and deposited into the annular space between the wellbore wall and the screens. Accordingly, the gravel forms a barrier to filter out the fines and sand from any produced fluids such that the fines and/or sand are prevented from entering the screens and being produced to the surface. This type of completion configuration is often referred to as an “open hole” completion or more specifically an “open hole gravel pack completion.”
Some embodiments disclosed herein include a production system for a subterranean wellbore. In an embodiment, the production system includes a production string disposed within the wellbore. The production string has a central axis and includes an axially extending internal throughbore. In addition, the production system includes a plurality of screens disposed along the production string. An annulus is formed between the production string and the wellbore that is in fluid communication with the internal throughbore via the plurality of screens. Further, the production system includes a bypass device coupled to the production string. The bypass device includes an inlet assembly and a shunt tube coupled to the inlet assembly. The shunt tube is in fluid communication with the annulus. The inlet assembly includes a plurality of inlet flow paths extending helically about the central axis from an uphole end of the inlet assembly. The inlet flow paths are fluidly coupled to the annulus and extend at least 3600 about the central axis. In addition, the inlet assembly includes an outlet flow path extending to a downhole end of the inlet assembly. The outlet flow path is fluidly coupled to the shunt tube and the plurality of inlet flow paths.
In another embodiment, the production system includes a production string disposed within the wellbore. The production string has a central axis and includes an axially extending internal throughbore. In addition, the production system includes a plurality of screens disposed along the production string. An annulus is formed between the production string and the wellbore that is in fluid communication with the internal throughbore via the plurality of screens. Further, the production system includes a bypass device coupled to the production string. The bypass device includes an inlet assembly and a shunt tube coupled to the inlet assembly. The shunt tube is in fluid communication with the annulus. The inlet assembly includes a first body member disposed about the production string, and a second body disposed about the production string. The second body member is downhole of and axially spaced from the first body member. In addition, the inlet assembly includes at least one inlet flow path within the first body member that is fluidly coupled to the annulus. Further, the inlet assembly includes a manifold axially disposed between the first body member and the second body member and fluidly coupled to the at least one inlet flow path. Further, the inlet assembly includes an outlet flow path fluidly coupled to the shunt tube and the manifold.
In another embodiment, the production system includes a production string disposed within the wellbore. The production string has a central axis and includes an axially extending internal throughbore. In addition, the production system includes a plurality of screens disposed along the production string. An annulus is formed between the production string and the wellbore that is in fluid communication with the internal throughbore via the plurality of screens. Further, the production system includes a bypass device coupled to the production string. The bypass device includes an inlet assembly and a shunt tube coupled to the inlet assembly. The shunt tube is in fluid communication with the annulus. The inlet assembly includes a first body member disposed about the production string, and a second body disposed about the production string. The second body member is downhole of and axially spaced from the first body member. In addition, the inlet assembly includes an inlet flow path within the second body member that is fluidly coupled to the annulus. Further, the inlet assembly includes an outlet flow path within the second body member that is fluid coupled to the annulus and the shunt tube. Still further, the inlet assembly includes a manifold fluidly axially disposed between the first body member and the second body member and fluidly coupled to the inlet flow path and the outlet flow path.
Embodiments described herein comprise a combination of features and characteristics intended to address various shortcomings associated with certain prior devices, systems, and methods. The foregoing has outlined rather broadly the features and technical characteristics of the disclosed embodiments in order that the detailed description that follows may be better understood. The various characteristics and features described above, as well as others, will be readily apparent to those skilled in the art upon reading the following detailed description, and by referring to the accompanying drawings. It should be appreciated that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes as the disclosed embodiments. It should also be realized that such equivalent constructions do not depart from the spirit and scope of the principles disclosed herein.
For a detailed description of various embodiments, reference will now be made to the accompanying drawings in which:
The following discussion is directed to various exemplary embodiments. However, one of ordinary skill in the art will understand that the examples disclosed herein have broad application, and that the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.
The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.
In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .” Also, the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection of the two devices, or through an indirect connection that is established via other devices, components, nodes, and connections. In addition, as used herein, the terms “axial” and “axially” generally mean along or parallel to a given axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the given axis. For instance, an axial distance refers to a distance measured along or parallel to the axis, and a radial distance means a distance measured perpendicular to the axis. Further, as used herein, the terms “circumferentially spaced” and “circumferential spacing” refer to the spacing about the circumferential or angular direction of a central axis. As a result, the term “uniformly circumferentially spaced” refers to equal or substantially equal spacing of the object or feature in question about a central axis (e.g., four objects placed every 900 about a central axis, three objects every 120° about a central axis, etc.). As used herein, the terms substantial, substantially, generally, about, approximately, and the like mean+/−10%. Finally, any reference to up or down in the description and the claims is made for purposes of clarity, with “up”, “upper”, “upwardly”, “uphole”, or “upstream” meaning toward the surface of the wellbore or borehole and with “down”, “lower”, “downwardly”, “downhole”, or “downstream” meaning toward the terminal end of the wellbore or borehole, regardless of the wellbore or borehole orientation.
Referring now to
A casing or liner pipe 16 (or more simply “casing 16”) is installed (e.g., cemented) within vertical section 12 such that fluid communication between surface 13 and wellbore 8 between the walls of vertical section 12 and casing 16 is prevented. A tubular completion or production string 18 extends within wellbore 8 through vertical section 12 and lateral section 14 and includes a first or upper section 18a extending from a surface structure 11 at surface 13 (which may comprise any suitable structure or equipment for drilling, servicing, or producing a subterranean wellbore), through casing 16 to a cross-over section 18b, and a lower section 18c extending from cross-over section 18b through lateral section 16 to a lower terminal end 18d. Lower section 18c includes one or more screens 19 that allow the passage of fluids into a central bore of lower section 18c (the central bore of lower section 18c is not specifically shown in
A first or upper annulus or annular region 20 is formed radially between upper section 18a and the inner surface of casing pipe 16. A second or lower annulus or annular region 26 is formed radially between lower section 18c and the inner wall of lateral section 14 of wellbore 8. A lower sealing assembly 22 is disposed at the downhole end of casing 16 that seals or closes off upper annulus 20 from lower annulus 26. As a result, fluid is prevented from flowing or migrating directly between upper annulus 20 and lower annulus 26. Cross-over section 18b includes one or more flow paths 24 that are configured to route fluids pumped or flowed down the central bore of upper section 18a into the lower annulus 26, and one or more flow paths 25 that are configured to route fluids pumped or flowed up through the central bore of lower section 18c into upper annulus 20. The specific design and arrangement of cross-over section 18b (including flow paths 24, 25) are not described in detail herein; however, one having ordinary skill would understand how such a device would operate to allow the fluid flow paths described above. In particular, in some embodiments, cross-over section 18b may comprise one or more connected (e.g., threadably connected) subs or members that define flow paths 24, 25.
During an open hole gravel pack completion operation, a slurry comprising a carrier fluid and gravel is pumped from surface structure 11 through the central bore of upper section 18a and then into lower annulus 26 via flow paths 24 in cross-over section 18b. The slurry flows through lower annulus 26 such that the gravel is deposited into annulus 26 and the carrier fluid is routed back into a central bore of lower production section 18c through the one or more screens 19. The carrier fluid is finally flowed back uphole to the upper annulus 20 (and ultimately surface 13) via flow paths 25 in cross-over section 18b. As a result, screens 19 of lower section 18c may be sized so as to prevent the passage of the gravel therethrough.
It is imperative that gravel is deposited throughout the entire lower annulus 26 as uniformly as possible, since any gaps or holes in the gravel pack will provide a flow path for sand and fines of producing zone 17 to enter lower section 18c (via screens 19) and then up to surface 13, which is undesirable for the reasons previously described above. However, during an open hole completion operation, such as described above, gravel can accumulate at points within lower annulus 26 such that bridges or blockages are created that prevent further downhole progress of slurry thereafter. Such a failure can cause entire portions or sections of lower annulus 26 to be substantially devoid of gravel, so that production from these un-completed sections of wellbore 8 may ultimately need to be abandoned.
To mitigate the effects of blockages formed within lower annulus 26 during completion operations and therefore prevent these losses of production from wellbore 8, production string 18 further includes a bypass device 100 that provides alternative flow paths for slurry within lower annulus 26. As a result, bypass device 100 allows the slurry to effectively bypass (or flow around) any gravel bridges or other blockages within annulus 26 such that a more uniform gravel pack can be achieved in lower annulus 26 during completion operations. In this embodiment, bypass device 100 are disposed about lower section 18c of production string 18, uphole of screens 19.
As is generally shown in
While not specifically shown, outlets 103 may comprise one or more nozzles or other suitable communication devices for flowing fluids from between outlets 103 and lower annulus 26 during operations. Thus, inlet assembly 101 defines internal alternative flow paths that allow slurry to flow from lower annulus 26 into shunt tubes 102. Thereafter, the slurry returns to lower annulus 26 at a lower (or more downhole) position by exiting shunt tubes 102 either at a terminal downhole end of shunt tubes 102 and/or at one or more of the outlets 103. As a result, any bridges or blockages within annulus 26 disposed axially between inlet assembly 101 and the outlets 103 or end of shunt tubes 102 may be bypassed by the slurry during operations.
Referring now to
In this embodiment, each bypass device includes inlet assembly 101 and one or more shunt tubes 102. While note specifically shown, shunt tubes 102 may also include one or more of the outlets 103 previously described above. During operations, inlet assemblies 101 define internal alternative flow paths that allow slurry to flow from lower annulus 26 into shunt tubes 102. Thereafter, the slurry returns to lower annulus 26 at a lower (or more downhole) position by exiting shunt tubes 102 either at a terminal downhole end of the shunt tubes 102 and/or at one or more of the outlets 103 (not shown—see
Referring now to
In some instances, internal blockages within bypass devices 100 results from the large accumulation or concentration of gravel that tends to settle toward the vertically lower side of lateral section 14 under the force of gravity. Such an over accumulation or concentration of gravel can then enter and ultimately block the alternative flow paths provided by bypass devices 100. The likelihood of such a failure is especially increased when the inlet ports to the alternative flow paths within bypass devices 100 are disposed toward the lower side of annulus 26.
To address these operational difficulties, bypass devices 100 (and particularly entry assemblies 101) are particularly designed to prevent blockages within the alternative flow paths provided within devices 100 such that the functionality of devices 100 is maintained during a completion operation. As a result, through use of the embodiments disclosed herein, a more uniform gravel pack within a subterranean wellbore (e.g., wellbore 8) may be more consistently achieved, such that the potential for lost production from such a wellbore may be decreased overall. Various embodiments of bypass devices 100 are contemplated herein and are described in more detail below with reference to
Referring now to
Referring particular now to
Body 130 is a tubular member that includes a first end 130a, a second end 130b opposite first end 130a, and a cylindrical through passage 132 defined by an innermost cylindrical surface 130d (see
Referring specifically again to
Referring now to
Referring again to
Referring still to
First ends 142a, 144a, 146a, 148a of inlet channels 142, 144, 146, 148 are each disposed at frustoconical surface 134 and each of the second ends 142b, 144b, 146b, 148b is disposed along one of the outlet channels 141, 143. Specifically, second ends 142b, 144b are disposed along outlet channel 141, with second 144b of channel 144 disposed at first end 141a and second end 142b of channel 142 disposed along channel 141 between ends 141a, 141b. In addition, second ends 146b, 148b are disposed along outlet channel 143, with second 148b of channel 148 disposed at first end 143a and second end 146b of channel 146 disposed along channel 143 between ends 143a, 143b. Thus, inlet channels 142, 144 are in communication with outlet channel 141, and inlet channels 146, 148 are in communication with outlet channel 143. As a result: (1) fluid flowing from first end 142a of channel 142 will communicate with channel 141 via the intersection between end 142b and channel 141; (2) fluid flowing from first end 144a of channel 144 will communicate with channel 141 via the intersection between ends 144b and 141a; (3) fluid flowing from first end 146a of channel 146 will communicate with channel 143 via the intersection between end 146b and channel 143; and (4) fluid flowing from first end 148a of channel 148 will communicate with channel 143 via the intersection between ends 148b and 143a.
Referring specifically to
In some embodiments, inlet channels 142, 144, 146, 148 may include burst discs or other pressure actuated valve members (e.g., valves) that only allow flow of fluid into channels 142, 144, 146, 148 (and therefore into channels 141, 143) when a certain pressure differential is reached.
Referring again to
Due to the helical orientation and path of inlet channels 142, 144, 146, 148, slurry flowing through channels 142, 144, 146, and 148 may flow “uphill” (or against the force of gravity) for at least some portion of inlet channels 142, 144, 146, 148 prior to the slurry entering outlet channels 141, 143 and thus shunt tubes 102. This uphill flow prevents large slugs or accumulations of gravel from advancing through inlet channels 142, 144, 146, 148 to outlet channels 141, 143 and shunt tubes 102, and instead tends to allow only relatively small concentrations of gravel to advance into outlet channels 141, 143 and shunt tubes 102. As a result, blockages of outlet channels 141, 143 and shunt tubes 102 are prevented (or at least reduced in likelihood), such that fluid communication along the alternative flow paths provided by bypass device 100 may be maintained. In addition, because inlet channels 142, 144, 146, 148 are uniformly circumferentially spaced about axis 55 along body 130, at least some number (e.g., two or three) or the inlet channels 142, 144, 146, 148 may be disposed at the vertically uppermost side of production string 18 within lateral section 14 (relative to the direction of gravity), thereby further preventing the larger accumulations of gravel (which tend to settle toward the vertically bottom side of lateral section 14 as previously described) from entering at least some of the inlet channels in the first place.
Therefore, employing bypass devices 100 along a production string 18 can help to ensure a more complete disbursement of gravel within annulus 26 during completion operations. As a result, use of bypass devices 100 may decrease the chances of lost production from wellbore 8 due to gaps or holes in the gravel pack of lower annulus 26.
Referring briefly now to
By including an increased number of inlet flow channels (e.g., flow channels 241, 242, 243, 244, 245, 246), additional flow paths are created within bypass assembly 100. As a result, it is less likely that all available flow paths through body 230 will be blocked during the completion operations described above. Accordingly, employing body 230 within bypass device 100 in place of body 130 may further enhance the reliability of such completion operations within wellbore 8.
Referring now to
Body 330 includes a plurality of helically extending inlet flow channels 342, 344, 346, 348, a pair of axially extending outlet flow channels 341, 343, and a common manifold channel 350 disposed axially between inlet flow channels 342, 344, 346, 348 and outlet flow channels 341, 343. Each of the inlet flow channels 342, 344, 346, 348, outlet flow channels 341, 343, and manifold 350 extend radially inward from radially outermost cylindrical surface 330c of body 330. In addition, each inlet flow channel 342, 344, 346, 348 extends helically from first end 330a to manifold channel 350, and each outlet flow channel 341, 343 extends axially from manifold channel 350 to second end 330b of body 330. As previously described above for body 130, when shroud 120 (see
When body 330 is included within bypass device 100 in place of body 130, fluid (e.g., slurry) is allowed to flow through one or more of the inlet flow channels 342, 344, 346, 348, into manifold 350, and out of one or both of outlet flow channels 341, 343, which would be coupled or mounted to or integral with shunt tubes 102 in the same manner described above for outlet flow channels 141, 143 of body 130. In some embodiments, inlet flow channels 342, 344, 346, 348 are uniformly circumferentially spaced about axis 55 such that each channel 343, 344, 346, 348 is circumferentially spaced approximately 90° from each immediately circumferentially adjacent inlet flow channel.
During operations, the helical path of inlet flow channels 342, 344, 346, 348 provides the same “uphill” flow for any slurry passing therethrough as described above for bypass device 100 and body 130. Therefore, large slugs or accumulations of gravel may not pass into the manifold 350 and outlet channels 341, 343 in substantially the same manner as previously described for body 130. In addition, as with body 130, the uniform circumferential spacing of inlet channels 342, 344, 346, 348 about axis 55 ensures that at least some of the inlet flow channels are disposed toward the vertical upper side of production string 18 thereby decreasing the likelihood that large accumulations of gravel will not enter at least some of the inlet flow channels 342, 344, 346, 348 in the first place. Finally, during operations, if accumulations or slugs of gravel should pass through inlet flow channels 342, 344, 346, 348, the relatively larger volume of manifold 350 may allow any such slugs or accumulations to diffuse and thus prevent such accumulations from further blocking outlet flow channels 341, 343 or shunt tube(s) 102 coupled thereto (see
Referring now to
During operations, body 430 provides similar functionality as body 330 except that body 430 includes still additional inlet flow channels (e.g., inlet flow channels 441, 442, 443, 444, 445, 446) such that the likelihood of a complete blockage of fluid flow through the combined channels 441, 442, 443, 444, 445, 446, 341, 343 is further reduced.
Referring now to
First body member 530 includes a first end 530a, a second end 530b opposite first end 530a, and an innermost cylindrical surface 530d extending axially between ends 530a, 530b. Second body member 531 includes a first end 531a, a second end 531b opposite first end 531a, and an innermost cylindrical surface 531d extending axially between ends 531a, 531b. In this embodiment, bypass device 500 is oriented such that first body member 530 is disposed uphole of second body member 531 and first ends 530a, 531a of body members 530, 531, respectively are uphole of second ends 530b, 531b, respectively. In addition, first body member 530 includes a frustoconical surface 534 extending from first end 530a toward second end 530b, and second body member 531 includes a frustoconical surface 536 extending from second end 531b toward first end 531a. Further, first body member 530 includes a radially outermost cylindrical surface 530c extending axially from frustoconical surface 534 to second end 530b, and second body member 531 includes a radially outermost cylindrical surface 531c extending axially from first end 531a to frustoconical surface 536. First body member 530 and second body member 531 are each disposed about tube 50 such that body members 530, 531 are axially separated or spaced from one another.
Shroud 520 includes a first end 520a, a second end 520b opposite first end 520a, a radially innermost cylindrical surface 520c extending axially between ends 520a, 520b, and a radially outermost cylindrical surface 520d also extending axially between ends 520a, 520b. Shroud 520 is disposed about body members 530, 531 such that first end 520a is proximate first end 530a of first body member 530, second end 520b is proximate second end 531b of second body member 531, and radially innermost cylindrical surface 520d engages with each of the radially outermost cylindrical surface 530c of first body member 530 and the radially outermost cylindrical surface 531c of second body member 531. In this embodiment ends 520a, 520b of cover 520 are disposed axially between frustoconical surfaces 534, 536 such that shroud 520 only extends axially over outermost cylindrical surfaces 530c, 531c of body members 530, 531 (see
Referring now to
Referring now to
Referring specifically again to
Referring again to
Because inlet flow tubes 561, 562, 563, 564, 565, 566, 567, 568 are uniformly circumferentially spaced about axis 55 along body 530, at least some number of the inlet tubes 561, 562, 563, 564, 565, 566, 567, 568 may be disposed at the vertically uppermost side of production string 18 within lateral section 14, thereby further preventing the larger accumulations of gravel (which tend to settle toward the vertically bottom portion of the lateral section 14 of wellbore 8 as previously described) from entering at least some of the inlet flow tubes 561, 562, 563, 564, 565, 566, 567, 568 in the first place. In addition, during operations, if accumulations or slugs of gravel should pass through inlet flow tubes 561, 562, 563, 564, 565, 566, 567, 568, the relatively larger volume of manifold 550 may allow any such slugs or accumulations to diffuse and thus prevent such accumulations from further blocking outlet flow channels 541, 543 or shunt tube(s) 102 coupled thereto (see
Therefore, employing bypass devices 500 along a production string 18 can help to ensure a more complete disbursement of gravel within annulus 26 during completion operations. As a result, use of bypass devices 500 may decrease the chances of lost production from wellbore 8 due to gaps or holes in the gravel pack of lower annulus 26.
Referring now to
First body member 630 includes a first end 630a, a second end 630b opposite first end 630a, and an innermost cylindrical surface 630d extending axially between ends 630a, 630b. Second body member 631 includes a first end 631a, a second end 631b opposite first end 631a, and an innermost cylindrical surface 631d extending axially between ends 631a, 631b. In this embodiment, bypass device 600 is oriented such that first body member 630 is disposed uphole of second body member 631 and first ends 630a, 631a of body members 630, 631, respectively are uphole of second ends 630b, 631b, respectively. In addition, body member 630 includes a frustoconical surface 634 extending from first end 630a toward second end 630b, and second body member 631 includes a frustoconical surface 636 extending from second end 631b toward first end 631a. Further, first body member 630 includes a radially outermost cylindrical surface 630c extending axially from frustoconical surface 634 to second end 630b, and second body member 631 includes a radially outermost cylindrical surface 631c extending axially from first end 631a to frustoconical surface 636. First body member 630 and second body member 631 are each disposed about tube 50 such that body members 630, 631 are axially separated or spaced from one another.
Shroud 620 includes a first end 620a, a second end 620b opposite first end 620a, a radially innermost cylindrical surface 620c extending axially between ends 620a, 620b, and a radially outermost cylindrical surface 620d also extending axially between ends 620a, 620b. Shroud 620 is disposed about body members 630, 631 such that first end 620a is proximate first end 630a of first body member 630, second end 620b is proximate second end 631b of second body member 631, and radially innermost cylindrical surface 620d engages with each of the radially outermost cylindrical surface 630c of first body member 630 and the radially outermost cylindrical surface 631c of second body member 631. In this embodiment ends 620a, 620b of cover 620 are disposed axially between frustoconical surfaces 634, 636 such that shroud 620 only extends axially over outermost cylindrical surfaces 630c, 631c of body members 630, 631 (see
Referring specifically to
In addition, as shown in
Referring still to
As shown in
Referring specifically now to
Referring again to
Because first body member 630 is free to pivot about axis 55 and thus self-orients itself to the vertically lower side of lateral section 14 of wellbore 8 under the force of gravity as previously described, inlet flow channel 640 should always be disposed at the vertically uppermost side of production string 18 within lateral section 14, thereby preventing larger accumulations of gravel (which tend to settle toward the vertically bottom portion of the wellbore and can cause a blockage within the alternative flow paths within bypass device 600 as previously described) from entering inlet flow channel 640 during operations. In addition, during operations, if accumulations or slugs of gravel should pass through inlet flow channels 640, the relatively larger volume of manifold 650 will allow any such slugs or accumulations to diffuse and thus prevent such accumulations from further blocking outlet flow channels 641, 643 or shunt tube(s) 102 coupled thereto (see
Therefore, employing bypass devices 600 along a production string 18 can help to ensure a more complete disbursement of gravel within annulus 26 during completion operations. As a result, use of bypass devices 600 may decrease the chances of lost production from wellbore 8 due to gaps or holes in the gravel pack of lower annulus 26.
Referring now to
First body member 730 includes a first end 730a, a second end 730b opposite first end 730a, and an innermost cylindrical surface 730d extending axially between ends 730a, 730b. Second body member 731 includes a first end 731a, a second end 731b opposite first end 731a, and an innermost cylindrical surface 731d extending axially between ends 731a, 731b. In this embodiment, bypass device 700 is oriented such that first body member 730 is disposed uphole of second body member 731 and first ends 730a, 731a of body members 730, 731, respectively are uphole of second ends 730b, 731b, respectively. In addition, first body member 730 includes a frustoconical surface 734 extending from first end 730a toward second end 730b, and second end 730b comprises a planar angled surface 738 that extends at an angle β relative to axis 55 that ranges from about 0° to about 90°. Further, second body member 731 includes a frustoconical surface 736 extending from second end 731b toward first end 731a, and first end 731a comprises a planar angled surface 737 that extends at an angle α relative to axis 55 that ranges from about 0° to about 90°. In this embodiment the angles β and α are the same; however, in other embodiments, the angles Rand a may be different. Further, first body member 730 includes a radially outermost cylindrical surface 730c extending axially from frustoconical surface 734 to planar angled surface 738, and second body member 631 includes a radially outermost cylindrical surface 731c (see
Shroud 720 includes a first end 720a, a second end 720b opposite first end 720a, a radially innermost cylindrical surface 720c extending axially between ends 720a, 720b, and a radially outermost cylindrical surface 720d also extending axially between ends 720a, 720b. Shroud 720 is disposed about body members 730, 731 such that first end 720a is proximate first end 730a of first body member 730, second end 720b is proximate second end 731b of second body member 731, and radially innermost cylindrical surface 720d engages with each of the radially outermost cylindrical surface 730c of first body member 730 and the radially outermost cylindrical surface 731c of second body member 731. In this embodiment ends 720a, 720b of shroud 720 are disposed axially between frustoconical surfaces 734, 736 such that shroud 720 only extends axially over outermost cylindrical surfaces 730c, 731c of body members 730, 731.
Referring still to
Referring specifically now to
Referring again to
Because inlet flow channels 742, 744 are disposed on second body member 731, slurry must enter inlet flow channels 742, 744 from the downhole end of bypass device 700. As a result, the general downhole flow direction of the slurry (due to both gravity and the pressure differential caused by the pumping of slurry into the wellbore) any large accumulations or slugs of gravel within the slurry will tend to continue flowing downhole past inlet flow channels 742, 744 and will therefore be prevented from entering inlet flow channels 742, 744. Therefore, there is a reduced likelihood that such slugs or accumulations of gravel will form a blockage within inlet flow channels 742, 744 during operations. In addition, during operations, if accumulations or slugs of gravel should pass through inlet flow channels 742, 744, the relatively larger volume of manifold 750 will allow any such slugs or accumulations to diffuse and thus prevent such accumulations from further blocking outlet flow channels 741, 743 or shunt tubes 102 coupled thereto (see
Therefore, employing bypass devices 700 along a production string 18 can help to ensure a more complete disbursement of gravel within annulus 26 during completion operations. As a result, use of bypass devices 700 may decrease the chances of lost production from wellbore 8 due to gaps or holes in the gravel pack of lower annulus 26.
While exemplary embodiments have been shown and described, other modifications thereof can be made by one skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary only and are not limiting. Many variations and modifications of the systems, apparatus, and processes described herein are possible and are within the scope of the disclosure. Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the steps in a method claim may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (1), (2), (3) before steps in a method claim are not intended to and do not specify a particular order to the steps, but rather are used to simplify subsequent reference to such steps.
This application claims benefit of U.S. provisional patent application Ser. No. 62/671,250 filed May 14, 2018, and entitled “Bypass Devices For A Subterranean Wellbore,” which is hereby incorporated herein by reference in its entirety.
Number | Name | Date | Kind |
---|---|---|---|
7207383 | Hurst et al. | Apr 2007 | B2 |
8371386 | Malone | Feb 2013 | B2 |
9309751 | Hall | Apr 2016 | B2 |
10145219 | Bourgneuf | Dec 2018 | B2 |
20070131421 | Hurst et al. | Jun 2007 | A1 |
20130277053 | Yeh et al. | Oct 2013 | A1 |
20140008066 | Least | Jan 2014 | A1 |
20140110132 | Cunningham | Apr 2014 | A1 |
20140262260 | Mayer | Sep 2014 | A1 |
20150337622 | Lopez | Nov 2015 | A1 |
20170204708 | Duphorne | Jul 2017 | A1 |
20180347311 | Coffin | Dec 2018 | A1 |
20190309605 | Greci | Oct 2019 | A1 |
Number | Date | Country |
---|---|---|
20130187878 | Dec 2013 | WO |
20170155546 | Sep 2017 | WO |
Entry |
---|
Partial International Search Report dated Aug. 1, 2019, for PCT/US2019/031682, filed on May 10, 2019. |
International Search Report and Written Opinion dated Sep. 18, 2019, for PCT/US2019/031682, filed on May 10, 2019. |
Number | Date | Country | |
---|---|---|---|
20190345799 A1 | Nov 2019 | US |
Number | Date | Country | |
---|---|---|---|
62671250 | May 2018 | US |