Patent Application
20130112410
None.
Not applicable.
Not applicable.
When wellbores are prepared for oil and gas production, it is common to cement a casing string within the wellbore. Often, it may be desirable to cement the casing within the wellbore in multiple, separate stages.
Conventionally, cementing a casing string within a wellbore is achieved by flowing cement to the bottom of the casing string and upward into the annular space between the casing string and the wellbore walls. In order to preserve the integrity of the cementitious slurry used to cement the casing within the wellbore, “cementing plugs” or “wiper plugs” are used to form a barrier between the cementitious slurry and other servicing fluids and reduce intermixing or intermingling between the cementitious slurry and any other fluid. It may be desirable to employ subsurface release cementing plugs, that is, cementing plugs that are released from a point within the wellbore below the Earth's surface, in a cementing operation. However, conventional subsurface release plugs are limited in application, for example, because of the relatively large diameter of conventional subsurface release cementing plug systems.
Therefore, there is a need for improved subsurface release plugs that may be employed in a wider range of applications.
Disclosed herein is a subsurface release plug release apparatus comprising a mandrel comprising a bottom plug portion, a top plug portion, a work string attachment portion, a first release portion between the bottom plug portion and the top plug portion, wherein the first release portion comprises a controlled strength segment configured to fail structurally and thereby release the bottom plug portion at a first fluid pressure, and a second release portion between the top plug portion and the work string attachment portion, wherein the second release portion is configured to release the bottom plug portion at a second fluid pressure, wherein the first fluid pressure is less than the second fluid pressure, a bottom plug body disposed about the bottom plug portion of the mandrel, and a top plug body disposed about the top plug portion of the mandrel.
Further disclosed herein is a wellbore servicing method comprising positioning a casing defining a flowbore within a wellbore with a subsurface release plug release apparatus disposed within a portion of the casing, the subsurface release plug release apparatus comprising a mandrel comprising a bottom plug portion, a top plug portion, a work string attachment portion, a first release portion between the bottom plug portion and the top plug portion, wherein the first release portion comprises a controlled strength segment configured to fail structurally and thereby release the bottom plug portion at a first fluid pressure, and a second release portion between the top plug portion and the work string attachment portion, wherein the second release portion is configured to release the bottom plug portion at a second fluid pressure, wherein the first fluid pressure is less than the second fluid pressure, a bottom plug body disposed about the bottom plug portion of the mandrel, and a top plug body disposed about the top plug portion of the mandrel, causing the first release portion to release the bottom plug portion by causing structural failure of the controlled strength segment, pumping a cementitious slurry via the flowbore of the casing, causing the second release portion to release the top plug portion, displacing the cementitious slurry from the flowbore of the casing into an annular space between the casing and a wellbore wall, and allowing the cementitious slurry to set.
Also disclosed herein is a wellbore servicing method comprising positioning a casing defining a flowbore within a wellbore with a subsurface release plug release apparatus disposed within a portion of the casing, the subsurface release plug release apparatus comprising a mandrel comprising a bottom plug portion, a top plug portion, a work string attachment portion, a first release portion between the bottom plug portion and the top plug portion, wherein the first release portion comprises a controlled strength segment configured to fail structurally and thereby release the bottom plug portion at a first fluid pressure, and a second release portion between the top plug portion and the work string attachment portion, wherein the second release portion is configured to release the top plug portion at a second fluid pressure, wherein the first fluid pressure is less than the second fluid pressure, a bottom plug body disposed about the bottom plug portion of the mandrel, and a top plug body disposed about the top plug portion of the mandrel, pumping a first obturating member to pass through the top plug portion of the mandrel and engage a first seat within the bottom plug portion of the mandrel, applying a fluid pressure to cause the first release portion to release the bottom plug portion by causing structural failure of the first controlled strength segment, pumping a second obturating member to engage a second seat within the top plug portion of the mandrel, and applying a fluid pressure to cause the second release portion to release the top plug portion.
Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.
Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “up-hole,” “upstream,” or other like terms shall be construed as generally from the formation toward the surface or toward the surface of a body of water; likewise, use of “down,” “lower,” “downward,” “down-hole,” “downstream,” or other like terms shall be construed as generally into the formation away from the surface or away from the surface of a body of water, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis.
Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.
Disclosed herein are one or more embodiments of a subsurface release plug (SRP) release apparatus, a SRP system, and methods using the same in the performance of a wellbore servicing operation. In an embodiment, such an SRP release apparatus or SRP system may be employed in the placement and cementing of a casing string within a wellbore.
Referring to
As depicted in
The wellbore 114 may extend substantially vertically away from the earth's surface over a vertical wellbore portion, or may deviate at any angle from the earth's surface 104 over a deviated or horizontal wellbore portion. In alternative operating environments, portions or substantially all of the wellbore 114 may be vertical, deviated, horizontal, and/or curved.
In embodiment, the wellbore 114 may be partially cased with a first casing string 120 and partially uncased. The first casing string 120 may be secured into position within the wellbore 114 in a conventional manner with cement 122, alternatively, the first casing string 120 may be partially cemented within the wellbore 120, alternatively, the first casing string may be uncemented. In an alternative embodiment, the wellbore 114 may be uncased and uncemented.
In the embodiment of
In the embodiment of
In one or more of the embodiments disclosed herein, a SRP release apparatus such as SRP release apparatus 200 may be discussed with reference to one or more figures. In these figures, the illustrated embodiments of the SRP release apparatus are generally oriented such that the upper-most (i.e., the furthest up-hole) end or portion of the SRP release apparatus 200 may be toward the left-hand side of such figure while the lower-most (i.e., the further down-hole) end or portion of the SRP release apparatus 200 may be toward the right-hand side of the figure. It is noted that reference herein to an upper, upper-most, up-hole, lower, lower-most, or down-hole, portion, segment, and/or component should not be construed as so-limiting unless otherwise specified. While the embodiments of a SRP release apparatus may be illustrated in a given configuration or orientation, one of skill in the art with the aid of this disclosure will appreciate that a SRP release apparatus may be suitably otherwise configured or oriented.
In the embodiment of
In the embodiment of
In an embodiment, the mandrel 210 may be characterized as comprising regions or segments having strengths that vary in comparison to each other. For example, the mandrel 210 may comprise two or more portions, regions, or segments exhibiting a relatively high strength. The mandrel 210 may also comprise one or more portions, regions, or segments exhibiting relatively intermediate strength in comparison to the high-strength portions. The mandrel 210 may also comprise one or more segments exhibiting relatively low strength in comparison to the intermediate strength portions. In the embodiment of
In an embodiment, the mandrel 210 may be formed from a suitable material. Examples of materials from which the mandrel may be formed include but are not limited to composite materials (examples of which will be discussed herein), metals and metal alloys, phenolic materials, rubbers, hardened plastics, cast materials, ceramic materials, resins, epoxies, or combinations thereof. Composite materials may include a reinforcing agent and a matrix material. In a fiber-based composite, fibers may act as the reinforcing agent. The matrix material may act to keep the fibers in a desired location and orientation and also serve as a load-transfer medium between fibers within the composite. In an embodiment, the materials from which the mandrel 210 is formed may be characterized as drillable materials.
In an embodiment, a mandrel having regions, portions, or segments having strengths that vary in comparison to each other, such as mandrel 210, comprises a fiber-wound composite formed by a fiber-winding process. Referring to
The binder surrounds and/or permeates the fibers. Suitable binder materials that may be used in the composite materials described herein may include, but are not limited to, thermosetting resins including orthophthalic polyesters, isophthalic polyesters, phthalic/maelic type polyesters, vinyl esters, thermosetting epoxies, phenolics, cyanates, bismaleimides, nadic end-capped polyimides (e.g., PMR-15), and any combinations thereof. Additional resin matrix materials may include thermoplastic resins including polysulfones, polyamides, polycarbonates, polyphenylene oxides, polysulfides, polyether ether ketones, polyether sulfones, polyamide-imides, polyetherimides, polyimides, polyarylates, liquid crystalline polyester, polyurethanes, polyureas, and any combinations thereof. In an embodiment, the binder material may comprise a two-component resin composition. Suitable two-component resin materials may include a hardenable resin and a hardening agent that, when combined, react to form a cured resin matrix material. Suitable hardenable resins that may be used include, but are not limited to, organic resins such as bisphenol A diglycidyl ether resins, butoxymethyl butyl glycidyl ether resins, bisphenol A-epichlorohydrin resins, bisphenol F resins, polyepoxide resins, novolak resins, polyester resins, phenol-aldehyde resins, urea-aldehyde resins, furan resins, urethane resins, glycidyl ether resins, other epoxide resins, and any combinations thereof. Suitable hardening agents that can be used include, but are not limited to, cyclo-aliphatic amines; aromatic amines; aliphatic amines; imidazole; pyrazole; pyrazine; pyrimidine; pyridazine; 1H-indazole; purine; phthalazine; naphthyridine; quinoxaline; quinazoline; phenazine; imidazolidine; cinnoline; imidazoline; 1,3,5-triazine; thiazole; pteridine; indazole; amines; polyamines; amides; polyamides; 2-ethyl-4-methyl imidazole; and any combinations thereof. In an embodiment, one or more additional components may be added the matrix material to affect the properties of the matrix material. For example, one or more elastomeric components (e.g., nitrile rubber) may be added to increase the flexibility of the resulting matrix material. Not intending to be bound by theory, the binder may act to hold the fibers together and retain the fibers in the desired orientation. In addition, the binder may protect the fibers. One skilled in the art may readily appreciate that the thickness and/or percentage of the binder may varied to meet a desired parameter.
In an embodiment, the mandrel 210 may be manufactured by a method comprising passing the fibers through a bath or solution of the binder solution and wrapping the binder-wetted fibers around the spindle 210A using a fiber wrapping machine or other similar apparatus, as will be appreciated by one of skill in the art viewing this disclosure. In an embodiment, the fibers may be wound via an automated or computed-driven machine, for example, as may be capable of winding the fibers to achieve one or more desired strength parameters or characteristics for the completed mandrel 210, as will be described herein. This step in the manufacturing process may be performed in a manufacturing shop or other similar facility. The spindle 210A may be secured at both ends and rotated as the fibers are wrapped around or otherwise applied about the spindle 210A from one end to the other and back again, continuing in a winding fashion until the fibers have been applied in the desired thickness and/or number of windings. In an embodiment, the fibers may be wound about the spindle 210A in alternating “hoop” and “helical” layers, where hoop layers refer to fibers wound circumferentially about the spindle 210A generally perpendicularly to longitudinal axis of the mandrel 210 and helical layers refer to fibers applied generally axially with respect to the longitudinal axis of the mandrel 210.
In an embodiment, one or more desired strength parameters or characteristics for the completed mandrel 210 may be designed and imparted dependent upon the way in which the fibers are applied to the spindle 210A at various positions or regions along the mandrel, for example, the number of windings of fibers wound around the spindle 210A, the direction and/or orientation of the fibers, the thickness of the composite 210B, or combinations thereof. For example, various strength characteristics and/or other mechanical properties may be adjusted by varying the winding angle of the fibers, altering the type and/or characteristics of the fiber material and/or the binder materials employed, or combinations thereof. As such, it is possible to manufacture mandrels having strength characteristics that vary at different portions or segments along the mandrel 210 by ranging the winding angle from about 0° to about −20° with respect to the longitudinal axis of the mandrel 210, altering the type of fiber, altering the thickness of the individual fibers, altering the thickness in which the fibers are applied, or combinations thereof. In an embodiment, to achieve the regions of varying strength, the fibers may be wound around the spindle 210A in a first orientation and/or thickness in a first region and a second orientation and/or thickness in a second region, thereby imparting differing strength parameters or characteristics to differing regions of the mandrel 210. For example, a relatively high strength portion of the mandrel may be wound with high strength carbon fibers and a relatively low strength portion of the mandrel may be wound with a lower strength fiber such as glass fibers. For example, the bias angle, the fiber type, fiber diameter, or combinations thereof may be varied to create areas along the mandrel having specific strength properties.
In an alternative embodiment, a mandrel like mandrel 210 having regions, portions, or segments having strengths that vary in comparison to each other may be manufactured by a milling process. In such an embodiment the mandrel 210 may be milled to comprise portions having one or more relatively reduced strength characteristics. For example, the mandrel 210 may comprise portions of reduced thickness, perforations, or other induced points of weakness, as will be appreciated by one of skill in the art viewing this disclosure.
In an embodiment, the mandrel 210, particularly, the work string attachment mandrel portion 260, may be configured to be connected to the lower end of the work string 150 via a suitable connection, for example, a threaded connection, a hammer joint, a collet, the like, or combinations thereof.
In an embodiment, the bottom plug mandrel portion 220 may be configured to receive and engage an obturating member (e.g., a dart or ball, as will be discussed herein). For example, the inner bore of the bottom plug mandrel portion 220 may comprise one or more seats comprising a shoulder, a chamfer, a bevel, or a similar reduction in the diameter of the inner bore surface that will receive and engage an obturating member of a given size and/or configuration. In the embodiment of
In an embodiment, the bottom plug mandrel portion 220 may be configured to allow pressure equalization between the axial flowbore 211 and the exterior of the mandrel 210. In the embodiment of
In an embodiment, the bottom plug mandrel portion 220 may be configured to be releasably secured to the bottom plug body 270 or vice versa. For example, the bottom plug mandrel portion 220 may comprise a groove or channel configured to receive a snap-ring, a bore configured to receive a shear pin or other frangible member, or the like. In the embodiment of
In an embodiment, the top plug mandrel portion 240 may be configured to receive and engage an obturating member (e.g., a dart or ball, as will be discussed herein). For example, the inner bore of the top plug mandrel portion 240 may comprise one or more seats comprising a shoulder, a chamfer, a bevel, or a similar reduction in the diameter of the inner bore surface that will receive and engage an obturating member of a given size and/or configuration. In the embodiment of
In an embodiment, the top plug mandrel portion 240 may be configured to secure such an obturating member (e.g., a dart or ball, as will be discussed herein) that engages the seat (e.g., chamfers 242) within the inner bore of the top plug mandrel portion 240. For example, the top plug mandrel portion 240 may comprise one or more recesses, grooves, shoulders, or channels configured to receive an expandable ring, a latch, a snap-ring, a pin, or the like associated with the obturating member. Alternatively, the top plug mandrel portion 240 may comprise a latch, a snap-ring, a pin, or combinations thereof to engage a groove and/or recess of an obturating member. In the embodiment of
In an embodiment, the top plug mandrel portion 240 may be configured to engage and be secured to the top plug body 280. For example, the top plug mandrel portion 240 may comprise a series of shoulders or bevels, a series of threads, a groove or channel configured to receive a snap-ring, a bore configured to receive a pin, or combinations thereof associated with the top plug body 230 (or vice versa). In the embodiment of
In the embodiment of
In an embodiment, the first controlled strength segment 230 may be characterized as exhibiting a strength, particularly, a tensile strength, less than the second controlled strength segment 250 and less than the body of the mandrel 210. In such an embodiment, the first controlled strength segment 230 may fail structurally when subjected to an internally applied fluid differential pressure greater than a given threshold while the second strength segment 250 and the body of the mandrel 210 will not. In an embodiment, the first controlled strength segment 230 may be characterized as having a predetermined tensile strength (referring to the amount of force applied in opposing directions along the longitudinal axis of the mandrel 210) that the first controlled strength segment is able to withstand. For example, the first controlled strength segment 230 may fail, causing the mandrel 210 to separate longitudinally, upon application of an internally applied fluid differential pressure greater than a given threshold. In an embodiment, such a threshold may be in the range of from about 800 psi to about 2,500 psi, alternatively, from about 1,000 psi to about 2,000 psi.
In the embodiment of
In an embodiment, the second controlled strength segment 250 may be characterized as exhibiting a strength, particularly, a tensile strength, greater than the first controlled strength segment 230 and less than the body of the mandrel 210. In such an embodiment, the second controlled strength segment 250 may fail structurally when subjected to an internally applied fluid differential pressure greater than a given threshold while the body of the mandrel 210 will not. In an embodiment, the second controlled strength segment 250 may be characterized as having a predetermined tensile strength (referring to the amount of force applied in opposing directions along the longitudinal axis of the mandrel 210) that the first controlled strength segment is able to withstand. For example, the second controlled strength segment 250 may fail, causing the mandrel 210 to separate longitudinally, upon application of an internally applied fluid pressure greater than a given threshold. In an embodiment, such a threshold may be in the range of from about 1,500 psi to about 5,500 psi, alternatively, from about 3,000 psi to about 4,000 psi.
Referring to
In the embodiment of
In the embodiment of
Referring again to
In an alternative embodiment, the bottom plug body 270 may be connected to the bottom plug mandrel portion 220 by a controlled strength area within the bottom plug body 270, a glue joint having a predetermined strength, a shouldered butt joint having a predetermined strength, or the like.
In an embodiment, the bottom plug body 270 may be configured to sealably engage an inner wall of a casing string, such as, casing 160. For example, in the embodiment of
In an embodiment, the bottom plug body 270 may be configured to engage a collar disposed within the casing 160, for example, a baffle adapter or landing collar such as landing collar 170, as will be discussed herein. For example, in the embodiment of
In an embodiment, the bottom plug body 270 may be configured to receive and engage the top plug body 280, as will be discussed herein. For example, in the embodiment of
In an embodiment, the top plug body 280 generally comprises a tubular body defining a bore extending longitudinally therethrough. As shown in
In an embodiment, the top plug body 280 may be configured to sealably engage an inner wall of a casing string, for example, casing 160. For example, in the embodiment of
In an embodiment, the top plug body 280 may be configured to engage the bottom plug, as will be discussed herein. For example, in the embodiment of
Referring again to
Referring to
In an embodiment, the longitudinal body 312 may be characterized as a shaft or mandrel. The longitudinal body 312 may be any suitable size, as will be appreciated by one of skill in the art viewing this disclosure. The longitudinal body 312 may be formed from a single piece, alternatively, the longitudinal body 312 may be formed from multiple operably-connected components (e.g., a plurality of body portions or segments connected by a threaded connection or the like).
In an embodiment, the wipers 315 may be configured to sealably engage an inner wall of the work string 150 and/or the inner walls of the mandrel 210 of the SRP release apparatus 200. The wipers 315 may be provided in a suitable number and configuration, as will be appreciated by one of skill in the art viewing this disclosure. For example, the embodiment of
In an embodiment, the bottom plug launching member 310 may be configured to engage and be retained within the bottom plug mandrel portion 220. For example, in the embodiment of
Referring to
In an embodiment, the longitudinal body 322 may be characterized as a shaft or mandrel. The longitudinal body 322 may be any suitable size, as will be appreciated by one of skill in the art viewing this disclosure. The longitudinal body 322 may be formed from a single piece, alternatively, the longitudinal body 322 may be formed from multiple operably-connected components (e.g., a plurality of body portions or segments connected by a threaded connection or the like).
In an embodiment, the wipers 325 may be configured to sealably engage an inner wall of the work string 150 and/or the inner walls of the mandrel 210 of the SRP release apparatus 200. The wipers 325 may be provided in a suitable number and configuration, as will be appreciated by one of skill in the art viewing this disclosure. For example, the embodiment of
In an embodiment, the top plug launching member 320 may be configured to engage and be retained within the top plug mandrel portion 240. For example, in the embodiment of
In an embodiment, the top plug launching member 320 may be configured to lock within the top plug mandrel portion 240. For example, in the embodiment of
In the embodiment of
In the embodiment of
In the embodiment of
Also disclosed herein are one or more wellbore servicing methods employing an SRP release apparatus like SRP release apparatus 200 or 400 disclosed herein and/or an SRP system like SRP system 100 disclosed herein. In an embodiment, the SRP release apparatus 200 or 400 and/or the SRP system 100 may be employed in the performance of a cementing operation.
In an embodiment, a wellbore servicing method employing the SRP release apparatus and/or the SRP system may generally include the steps of positioning the SRP release apparatus within a casing string within a wellbore, releasing the bottom plug, circulating a cementitious slurry, releasing the top plug, displacing the at least a portion of the cementitious slurry into an annualar space, and allowing the cementitious slurry to set. In an embodiment, a wellbore servicing method may additionally and optionally include the step of removing the top plug and/or the bottom plug from the casing string.
In an embodiment, positioning the SRP release apparatus 200, 400 within a casing string within a wellbore may comprise positioning a casing string such as casing 160 within the wellbore 114 while attached to the downhole terminal end of a work string such as work string 150. For example, as disclosed above, the casing 160 may be attached to the work string 150 via a liner hanger. The SRP release apparatus 200 may be attached to the work string 150 within a generally upper portion of the casing 160 and, as such, may be lowered into the wellbore 114 with the casing 160.
In an embodiment, releasing the bottom plug may generally comprise causing structural failure of the first controlled strength segment 230. In an embodiment, causing structural failure of the first controlled strength segment 230 may comprise deploying the bottom plug launching member 310 (e.g., via the operation of the dart-launching apparatus 300 located at the surface 104) and pumping the bottom plug launching member 310 downhole via the interior of the work string 150 to engage the seat within the bottom plug mandrel portion 220, as illustrated in
In an embodiment, after the bottom plug launching member 310 has been deployed from the surface 104, a cementitious slurry may be forward-circulated via the interior of the work string 150 directly behind the bottom plug launching member 310 (or, optionally, with a small volume of a spacer fluid between the cementitious slurry and the bottom plug launching member 310). Because the wipers 315 of the bottom plug launching member 310 sealably or substantially sealably engage the inner walls of the work string 150, the cementitious slurry is not intermingled or intermixed with (and, therefore, is not contaminated by) any fluid which may have been previously pumped via the work string 150.
In an embodiment, once the bottom plug launching member 310 reaches and engages the bottom plug mandrel portion 220 (thereby sealing the interior flow path), continued pumping will increase the force applied to the mandrel 210. Referring to
In an embodiment, port(s) 224 may prevent a pressure build-up (e.g., resulting from trapped pressure) between the top body 280 and bottom plug body 270 due to abrupt pressure changes that may occur while circulating and/or flowing a fluid prior to releasing the bottom plug. The port(s) 224 are bridged and sealed off on both sides of the port(s) when the bottom plug launching member 310 lands in the bottom plug mandrel portion 220 as illustrated in
In an embodiment, the cementitious slurry continues to be pumped downhole until a desired volume of the cementitious slurry (e.g., a volume necessary to cement the casing 160 in place) has been pumped. The cementitious slurry will flow downward within the work string 150 through the SRP release apparatus and into the casing 160 behind the bottom plug 600. Because the wipers 275 of the bottom plug 600 sealably or substantially sealably engage the inner walls of the casing 160, the cementitious slurry is not intermingled or intermixed with (and, therefore, is not contaminated by) any fluid which may have been previously pumped via the casing 160.
Referring to
Referring to
In an embodiment, releasing the top plug may generally comprise causing structural failure of the second controlled strength segment 250. In an embodiment, causing structural failure of the second controlled strength segment 250 may comprise deploying the top plug launching member 320 (e.g., via the operation of the dart-launching apparatus 300 located at the surface 104) and pumping the top plug launching member 320 downhole via interior of the work string 150 to engage the seat within the top plug mandrel portion 240, as illustrated in
In an embodiment, after the top plug launching member 320 has been deployed from the surface 104, a servicing fluid may be forward-circulated via the work string 150 directly behind the top plug launching member 320, thereby displacing at least a portion of the cementitious slurry into the annular space between the casing 160 and a wall of the wellbore 114. Because the wipers 325 of the top plug launching member 320 sealably or substantially sealably engage the inner walls of the work string 150, the cementitious slurry is not intermingled or intermixed with (and, therefore, is not contaminated by) the servicing fluid which follows the top plug launching member within the work string 150.
In an embodiment, once the top plug launching member 320 engages the top plug mandrel portion 240 (thereby sealing the interior flow path), continued pumping will increase the force applied to the mandrel 210. Referring to
In an alternative embodiment where an SRP apparatus 400 is configured as disclosed with respect to
Referring to
In an embodiment, it may be desirable to remove the top plug 700, the bottom plug body 270, and/or the collar 170 from the casing 160. In an embodiment where these components are formed from drillable materials, removal may comprise “drilling out” these components. In alternative embodiments, one or more of these components may removable by degradation, consumption, or other means known to one of skill in the art viewing this disclosure.
In an embodiment, the SRP release apparatus 200, 400 the SRP system 100, and/or the wellbore servicing methods employing the same as disclosed herein may be advantageously employed where prior art systems could not have been employed. For example, in an embodiment the SRP release apparatus 200, 400 and/or the SRP system 100 may be disposed within a relatively small-diameter casing string, whereas prior art subsurface release cementing plugs, which were released from collets, were too restrictive (as to fluid flow) as to be applied to the design on small diameter plug sets. The SRP release apparatus 200, 400 and/or the SRP system 100 as disclosed herein may be employed within a casing sized about 4.5 inches through about 7 inches. For example, the SRP release apparatus 200, 400 and/or SRP system 100 may be utilized in conjunction with a casing comprising an inner diameter of about 3.83 inches, alternatively, an inner diameter of less than about 6.54 inches.
It is noted that although some of the figures may exemplify a given operating environment, the principles of the devices, systems, and methods disclosed may be similarly applicable in other operational environments, such as offshore and/or subsea wellbore applications.
The following are nonlimiting, specific embodiments in accordance with the present disclosure:
A subsurface release plug release apparatus comprising:
a mandrel comprising:
a bottom plug body disposed about the bottom plug portion of the mandrel; and
a top plug body disposed about the top plug portion of the mandrel.
The subsurface release plug release apparatus of Embodiment A, wherein the mandrel is manufactured by a process comprising winding a plurality of fibers around a mandrel template.
The subsurface release plug release apparatus of one of Embodiments A or B, wherein the bottom plug body is releasably secured to the bottom plug portion of the mandrel via a frangible member.
The subsurface release plug release apparatus of one of Embodiments A through C, wherein the bottom plug body is configured to engage and be retained by a landing collar integrated within a casing string.
The subsurface release plug release apparatus of one of Embodiments A through D, wherein the second release portion comprises a controlled strength segment configured to fail structurally and thereby release the top plug portion.
The subsurface release plug release apparatus of one of Embodiments A through D, wherein the second release portion comprises a collet configured to contract and thereby release the top plug portion.
The subsurface release plug release apparatus of one of Embodiments A through F, wherein the bottom plug portion is configured to sealably receive and retain a bottom plug launching member.
The subsurface release plug release apparatus of one of Embodiments A through G, wherein the top plug portion is configured to sealably receive and retain a top plug launching member.
The subsurface release plug release apparatus of one of Embodiments A through H, wherein the bottom plug mandrel portion further comprises a port, wherein the port is configured to equalize pressure between flowbore substantially defined by the mandrel and an exterior of the mandrel.
A wellbore servicing method comprising:
positioning a casing defining a flowbore within a wellbore with a subsurface release plug release apparatus disposed within a portion of the casing, the subsurface release plug release apparatus comprising:
causing the first release portion to release the bottom plug portion by causing structural failure of the controlled strength segment;
pumping a cementitious slurry via the flowbore of the casing;
causing the second release portion to release the top plug portion;
displacing the cementitious slurry from the flowbore of the casing into an annular space between the casing and a wellbore wall; and
allowing the cementitious slurry to set.
The wellbore servicing method of Embodiment J, wherein the mandrel is manufactured by a process comprising winding a plurality of fibers around a mandrel template.
The wellbore servicing method of one of Embodiments J or K, wherein the bottom plug body is releasably secured to the bottom plug portion of the mandrel via a frangible member.
The wellbore servicing method of one of Embodiments J through L, further comprising pumping the bottom plug body and the bottom plug portion of the mandrel downward through the flowbore of the casing to engage a collar integrated within the casing, wherein engaging the collar retains the bottom plug body.
The wellbore servicing method of one of Embodiments L or M, further comprising causing structural failure of the shear pin.
The wellbore servicing method of Embodiment N, further comprising pumping the bottom plug portion of the mandrel downward through the collar while the bottom plug body is retained by the collar.
The wellbore servicing method of Embodiment O, further comprising pumping the top plug body and the top plug portion of the mandrel downward through the flowbore of the casing to engage the bottom plug body.
The wellbore servicing method of one of Embodiments J through P, wherein the second release portion comprises a controlled strength segment configured to fail structurally and thereby release the top plug portion, and wherein causing the second release portion to release the top plug portion comprises causing structural failure of the controlled strength segment.
The wellbore servicing method of one of Embodiments J through P, wherein the second release portion comprises a collet configured to contract radially and thereby release the top plug portion, and wherein causing the second release portion to release the top plug portion comprises causing the collet to expand radially.
A wellbore servicing method comprising:
The method of Embodiment S, wherein the mandrel is manufactured by a process comprising winding a plurality of fibers around a mandrel template.
The method of one of Embodiments S or T, wherein the bottom plug body is releasably secured to the bottom plug portion of the mandrel via a frangible member.
The method of one of Embodiments S through U, further comprising pumping the bottom plug body and the bottom plug portion of the mandrel downward through the flowbore of the casing to engage a collar integrated within the casing, wherein engaging the collar retains the bottom plug body.
The wellbore servicing method of one of Embodiments U or V, further comprising causing structural failure of the frangible member.
The wellbore servicing method of Embodiment W, further comprising pumping the bottom plug body and the portion of the mandrel downward to engage a collar integrated within the casing, wherein the collar retains the bottom plug body.
The wellbore servicing method of Embodiment X, further comprising pumping the top plug body and the top plug portion of the mandrel downward through the flowbore of the casing to engage the bottom plug body.
The wellbore servicing method of one of Embodiments S through Y, wherein the second release portion comprises a controlled strength segment configured to fail structurally and thereby release the top plug portion, and wherein causing the second release portion to release the top plug portion comprises causing structural failure of the controlled strength segment.
The wellbore servicing method of one of Embodiments S through Y, wherein the second release portion comprises a collet configured to contract radially and thereby release the top plug portion, and wherein causing the second release portion to release the top plug portion comprises causing the collet to expand radially.
The wellbore servicing method of one of Embodiments S through AA, wherein the bottom plug portion of the mandrel comprises a port, and wherein the port provides fluid communication between an interior bore defined by the mandrel and an exterior portion of the mandrel between the bottom plug body and the top plug body prior to causing the bottom plug portion to be released.
While embodiments of the invention have been shown and described, modifications thereof can be made by one skilled in the art without departing from the spirit and teachings of the invention. The embodiments described herein are exemplary only, and are not intended to be limiting. Many variations and modifications of the invention disclosed herein are possible and are within the scope of the invention. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, R1, and an upper limit, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R═R1+k* (Ru−R1), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term “optionally” with respect to any element of a claim is intended to mean that the subject element is required, or alternatively, is not required. Both alternatives are intended to be within the scope of the claim. Use of broader terms such as comprises, includes, having, etc. should be understood to provide support for narrower terms such as consisting of, consisting essentially of, comprised substantially of, etc.
Accordingly, the scope of protection is not limited by the description set out above but is only limited by the claims which follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated into the specification as an embodiment of the present invention. Thus, the claims are a further description and are an addition to the embodiments of the present invention. The discussion of a reference in the Detailed Description of the Embodiments is not an admission that it is prior art to the present invention, especially any reference that may have a publication date after the priority date of this application. The disclosures of all patents, patent applications, and publications cited herein are hereby incorporated by reference, to the extent that they provide exemplary, procedural or other details supplementary to those set forth herein.
