Patent Application
20140196892
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Hydrocarbon-producing wells often are stimulated by hydraulic fracturing operations, wherein a servicing fluid such as a fracturing fluid or a perforating fluid may be introduced into a portion of a subterranean formation penetrated by a wellbore at a hydraulic pressure sufficient to create or enhance at least one fracture therein. Such a subterranean formation stimulation treatment may increase hydrocarbon production from the well.
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. Furthermore, stimulation equipment may be incorporated within the casing string for use in the overall production process. The casing and stimulation equipment may be run into the wellbore to a predetermined depth. Various “zones” in the subterranean formation may be isolated via the operation of one or more packers, which may also help to secure the casing string and stimulation equipment in place, and/or via cement.
Following placement of the casing string and stimulation equipment within the wellbore, it may be desirable to “pressure test” the casing string and stimulation equipment, to ensure the integrity of both, for example, to ensure that a hole or leak has not developed during placement of the casing string and stimulation equipment. Pressure-testing generally involves pumping a fluid into an axial flowbore of the casing string such that a pressure is internally applied to the casing string and the stimulation equipment and maintaining that hydraulic pressure for sufficient period of time to ensure the integrity of both, for example, to ensure that a hole or leak has not developed. To accomplish this, no fluid pathway out of the casing string can be open, for example, all ports or windows of the fracturing equipment, as well as any additional routes of fluid communication, must be closed or restricted.
Following the pressure test, it may be desirable to provide at least one route of fluid communication out of the casing string. Conventionally, the methods and/or tools employed to provide fluid pathways out of the casing string after the performance of a pressure test are configured to open upon exceeding the pressure levels achieved during pressure testing, thereby limiting the pressures that may be achieved during that pressure test. Such excessive pressure levels required to open the casing string may jeopardize the structural integrity of the casing string and/or stimulation equipment, for example, by requiring that the casing and/or various other wellbore servicing equipment components be subjected to pressures near or in excess of the pressures for which such casing string and/or wellbore servicing component may be rated. Thus, a need exists for improved pressure testing valves and methods of using the same.
Disclosed herein is a wellbore servicing system comprising a casing string, and a pressure testing valve, the pressure testing valve incorporated within the casing string and comprising a housing comprising one or more ports and an axial flowbore, a sliding sleeve, wherein the sliding sleeve is slidably positioned within the housing and transitional from a first position to a second position through a sliding sleeve stroke, wherein, when the sliding sleeve is in the first position, the sliding sleeve blocks a route of fluid communication via the one or more ports and, when the sliding sleeve is in the second position the sliding sleeve does not block the route of fluid communication via the one or more ports wherein the pressure testing valve is configured such that application of a predetermined pressure to the axial flowbore for a predetermined duration causes the sliding sleeve to transition from the first position to the second position, wherein the predetermined duration is at least about one minute.
Also disclosed herein is a wellbore servicing method comprising positioning casing string having a pressure testing valve incorporated therein within a wellbore penetrating the subterranean formation, wherein the pressure testing valve comprises a housing comprising one or more ports and an axial flowbore, and a sliding sleeve, wherein the sliding sleeve is slidably positioned within the housing, wherein the sliding sleeve is configured to block a route of fluid communication via one or more ports when the casing string is positioned within the wellbore applying a fluid pressure of at least a pressure threshold to the axial flowbore, wherein, upon application of the fluid pressure of at least the pressure threshold, the sliding sleeve continues to block the route of fluid communication via the one or more ports, and continuing to apply fluid pressure to the axial flowbore for a predetermined duration of time, wherein the predetermined duration is at least about one minute, and wherein, following the predetermined duration of time, the sliding sleeve allows fluid communication via one or more ports of the housing.
Further disclosed herein is a wellbore servicing method comprising positioning a casing string having a pressure testing valve incorporated therein within a wellbore penetrating a subterranean formation, pressurizing an axial flowbore of the casing string for a predetermined duration, wherein the pressure within the axial flowbore reaches at least a pressure threshold, wherein, upon pressurizing the axial flowbore for the predetermined duration, the pressure testing valve opens, and wherein a pressure substantially exceeding the pressure threshold is not applied to the casing string to open the pressure testing valve.
Further disclosed herein is a wellbore servicing method comprising pressure testing at a first pressure a tubing string positioned within a wellbore penetrating a subterranean formation, wherein the pressure test comprises an application of pressure for a predetermined duration, wherein during at least a portion of the predetermined duration, the application of pressure is of at least a pressure threshold, and wherein a pressure substantially exceeding the pressure threshold is not applied to the casing string during the pressure test, following the predetermined duration, flowing a fluid down the tubing string and into the wellbore or the subterranean formation.
Further disclosed herein is a pressure testing valve comprising a housing comprising one or more ports, a sliding sleeve, slidably positioned within the housing and movable from a first position with respect to the housing to a second position with respect to the housing, wherein, in the first position, the sliding sleeve blocks a route of fluid communication via the one or more port, and wherein, in the second position, the sliding sleeve does not block the route of fluid communication via the ports; and a fluid delay system, wherein the fluid delay system is generally configured to control the movement of the sliding sleeve from the first position to the second position.
For a more complete understanding of the present disclosure and the advantages thereof, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description:
In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. In addition, similar reference numerals may refer to similar components in different embodiments disclosed herein. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present disclosure is susceptible to embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is not intended to limit the invention to the embodiments illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.
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 embodiments of an interruptible pressure testing valve (IPTV), as well as systems and methods employing the same. Particularly, disclosed herein are one or more embodiments of a IPTV incorporated within a tubular string, for example, a casing string or liner, which may comprise one or more wellbore servicing tools positioned within a wellbore penetrating a subterranean formation.
Where a casing string has been placed within a wellbore and, for example, prior to the commencement of stimulation (e.g., perforating and/or fracturing) operations, it may be desirable to pressure test the casing string or liner and thereby verify its integrity and functionality. In the embodiments disclosed herein, an IPTV enables the casing string to be pressure tested and, subsequently, allows a route of fluid communication from a flowbore of the casing string to/into the wellbore and surrounding formation without the use of excessive pressure threshold levels. Additionally, such an IPTV enables a pressure test to be suspended (e.g., interrupted) after having been commenced and later resumed, for example, following repairs to a casing string.
Referring to
Referring to
In an embodiment the wellbore 114 may extend substantially vertically away from the earth's surface 104 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 an embodiment, a portion of the casing string 150 may be secured into position against the formation 102 in a conventional manner using cement 116. In alternative embodiment, the wellbore 114 may be partially cased and cemented thereby resulting in a portion of the wellbore 114 being uncemented. In an embodiment, an IPTV 100 or some part or component thereof may be incorporated within the casing string 150. The IPTV 100 may be delivered to a predetermined depth within the wellbore 114. It is noted that although the IPTV is disclosed as being incorporated within a casing string in one or more embodiments, the specification should not be construed as so-limiting. An IPTV may similarly be incorporated within other suitable tubulars such as a work string, liner, production string, a length of tubing, or the like. For example, in an alternative embodiment, the IPTV 100 or some part/component thereof may be integrated and/or incorporated within a liner.
Referring to
While the operating environment depicted in
In an embodiment, the IPTV 100 is selectively configurable to either allow or disallow a route of fluid communication from a flowbore 124 thereof and/or the casing flowbore 115 to the formation 102 and/or into the wellbore 114, as will be disclosed herein. Particularly, the IPTV 100 may be configured so as to allow such a route of fluid communication upon the application of a predetermined fluid pressure (e.g., a fluid pressure of at least a threshold pressure) to the IPTV 100 (e.g., to the flowbore 124 thereof) for a predetermined duration, as will be disclosed herein. Additionally, the IPTV 100 may be configured such that application of fluid pressure of at least the threshold pressure need not be continuous (e.g., the duration over which the pressure is applied need not be continuous). Also, the fluid pressure may vary over the predetermined duration.
Referring to
In an embodiment as depicted in
In an embodiment as depicted in
In an embodiment, the housing 120 of the IPTV 100 is a generally cylindrical or tubular-like structure. In an embodiment, the housing 120 generally defines an axial flowbore 124. The housing 120 may comprise a unitary structure; alternatively, the housing 120 may be made up of two or more operably connected components (e.g., an upper component, and a lower component, which may be joined via a suitable connection, such as a welded or threaded connection). Alternatively, a housing of an IPTV 100 may comprise any suitable structure; such suitable structures will be appreciated by those of skill in the art with the aid of this disclosure.
In an embodiment the IPTV 100 may be configured for incorporation into the casing string 150, for example, as illustrated by the embodiment of
Referring to
In an embodiment, the housing 120 may comprise one or more shoulders, surfaces, or the like, generally defining one or more inner cylindrical surfaces of various diameters. Referring to
In an embodiment, the housing 120 comprises one or more ports 122. In this embodiment, the ports 122 extend radially outward from and/or inward towards the axial flowbore 124. As such, these ports 122 may provide a route of fluid communication from the axial flowbore 124 to an exterior of the housing 120 when the IPTV 100 is so-configured. For example, the IPTV 100 may be configured such that the ports 122 provide a route of fluid communication between the axial flowbore 124 and the wellbore 114 and/or subterranean formation 102 when the ports 122 are unblocked (e.g., by the sliding sleeve 126, as will be disclosed herein). Alternatively, the IPTV 100 may be configured such that no fluid will be communicated via the ports 122 between the axial flowbore 124 and the wellbore 114 and/or the subterranean formation 102 when the ports 122 are blocked (e.g., by the sliding sleeve 126, as will be disclosed herein). In an embodiment, the ports 122 may be configured to communicate a fluid at a given rate and/or pressure. For example, in an embodiment, the ports 122 may be fitted with one or more pressure-altering devices (e.g., nozzles, erodible nozzles, fluid jets, or the like). In an additional embodiment, the ports 122 may be fitted with plugs, screens, covers, or shields, for example, to prevent debris from entering the ports 122.
Referring to
In an embodiment, the sliding sleeve 126 may comprise one or more of shoulders, or the like, generally defining one or more cylindrical surfaces of various diameters. Referring to
In an embodiment, the sliding sleeve 126 may further comprise a collar 141 disposed about the sliding sleeve 126. For example, in the embodiment of
In an embodiment, the sliding sleeve 126 may be slidably and concentrically positioned within the housing 120. In an embodiment, the sliding sleeve 126 may be slidably movable, with respect to the housing 120, from a first position to a second position with respect to the housing 120.
For example, in the embodiment of
In an embodiment, one or more of the interfaces between the sliding sleeve 126 and the housing 120 may be fluid-tight and/or substantially fluid-tight. For example, in an embodiment, the housing 120 and/or the sliding sleeve 126 may comprise one or more suitable seals at such an interface, for example, for the purpose of prohibiting or restricting fluid movement via such an interface. Suitable seals include but are not limited to a T-seal, an O-ring, a gasket, or combinations thereof. In the embodiment of
Additionally, in an embodiment, because the interface between the first bore surface 120a and the second outer cylindrical bore surface 126e and the interface between the second outer cylindrical bore surface 126e and the fourth bore surface 120d are fluidicly sealed (e.g., by fluid seals 136), as disclosed above, there is a resulting chamber 138 which is unexposed to hydraulic fluid pressures applied to the axial flowbore 124.
Also, in an embodiment (and dependent upon the position of the sliding sleeve 126 relative to the housing 120, as will be disclosed herein), the interface between the third outer cylindrical surface 141c (of the collar 141) and the second bore surface 120b of the housing 120 may be fluidicly sealed, for example, by a first fluid seal 142 (e.g., one or more O-rings or the like). Additionally, in the embodiment of
In an embodiment, the sliding sleeve 126 may be positioned so as to allow or disallow fluid communication via the one or more ports 122 between the axial flowbore 124 of the housing 120 and the exterior of the housing 120, dependent upon the position of the sliding sleeve 126 relative to the housing 120. Referring to
In an embodiment, the sliding sleeve 126 may be configured to be selectively transitioned from the first position to the second position. For example, in an embodiment the sliding sleeve 126 may be configured to transition from the first position to the second position (e.g., a sliding sleeve stroke) upon the application of a hydraulic pressure to the axial flowbore 124 for a predetermined duration (e.g., a pressure, over at least a portion of the predetermined duration, of at least a pressure threshold), as will be disclosed herein. In such an embodiment, the sliding sleeve 126 may comprise a differential in the surface area of the upward-facing surfaces which are fluidicly exposed to the axial flowbore 124 (e.g., the upper face 126a) and the surface area of the downward-facing surfaces which are fluidicly exposed to the axial flowbore 124 (e.g., the lower face 126c), for example, because the intermediate shoulder 126b is unexposed (e.g., is fluidicly sealed from the axial flowbore 124, as disclosed herein). For example, in the embodiment of
In an embodiment, the sliding sleeve 126 may be retained in the first position and/or the second position by a suitable retaining mechanism, as will be disclosed herein. For example, in the embodiment of
Also, in an additional or alternative embodiment, the sliding sleeve 126 may be retained in the second position by suitable a retaining mechanism. For example, in an embodiment, the sliding sleeve 126 may be retained in the second position by a snap-ring, alternatively, by a C-ring, a biased pin, ratchet teeth, or combinations thereof. In such an embodiment, the snap-ring (or the like) may be carried in a suitable slot, groove, channel, bore, or recess in the sliding sleeve, alternatively, in the housing, and may expand into and be received by a suitable slot groove, channel, bore, or recess in the housing, or, alternatively, in the sliding sleeve 126. Additionally or alternatively, the sliding sleeve 126 may be retained in the second position via the application of fluid pressure to the sliding sleeve 126, for example, resulting in a force in the direction of the second position via the differential in the forces applied to the sliding sleeve 126, as disclosed herein.
In an embodiment, the sliding sleeve 126 may be configured to transition from the first position to the second position at a controlled rate, at a predetermined rate, within a predetermined duration, or combinations thereof. For example, in an embodiment, the IPTV 100 may be configured such that the sliding sleeve 126 will transition from the first position to the second position within a predetermined duration of from about 5 minutes to about 120 minutes, alternatively, from about 15 minutes to about 60 minutes, alternatively, from about 20 minutes to about 40 minutes, alternatively of about 30 minutes, alternatively, any suitable duration. For example, in an embodiment, the IPTV 100 may be configured such that the sliding sleeve 126 will transition from the first position to the second position after a delay of greater than about 1, 3, 5, 7, 10, 15, 20, 25, 30, 35, 40, 45, 50, 55, 60, or more minutes.
For example, in an embodiment, the IPTV 100 may further comprise a delay system, such as a fluid delay system. For example, in an embodiment, the IPTV 100 comprises a metering check valve assembly 140. Referring to
In an embodiment, and as disclosed herein, the collar 141 may be slidably and concentrically positioned within the housing 120. For example, in the embodiment of
Also, as illustrated in the embodiment of
In an embodiment, the second chamber 138b may be filled and/or at least partially filled with a suitable fluid (e.g., a hydraulic fluid). In an embodiment, the fluid may be characterized as having a suitable rheology. In an embodiment, the fluid may be characterized as substantially incompressible. In an embodiment, the fluid may be characterized as having a suitable bulk modulus, for example, a relatively high bulk modulus. For example, in an embodiment, the fluid may be characterized as having a bulk modulus in the range of from about 1.8 105 psi, lbf/in2 to about 2.8 105 psi, lbf/in2 from about 1.9 105 psi, lbf/in2 to about 2.6 105 psi, lbf/in2, alternatively, from about 2.0 105 psi, lbf/in2 to about 2.4 105 psi, lbf/in2. In an additional embodiment, the fluid may be characterized as having a relatively low coefficient of thermal expansion. For example, in an embodiment, the fluid may be characterized as having a coefficient of thermal expansion in the range of from about 0.0004 cc/cc/° C. to about 0.0015 cc/cc/° C., alternatively, from about 0.0006 cc/cc/° C. to about 0.0013 cc/cc/° C., alternatively, from about 0.0007 cc/cc/° C. to about 0.0011 cc/cc/° C. In another additional embodiment, the fluid may be characterized as having a stable fluid viscosity across a relatively wide temperature range (e.g., a working range), for example, across a temperature range from about 50° F. to about 400° F., alternatively, from about 60° F. to about 350° F., alternatively, from about 70° F. to about 300° F. In another embodiment, the fluid may be characterized as having a viscosity in the range of from about 50 centistokes to about 500 centistokes. Examples of a suitable fluid include, but are not limited to oils, such as synthetic fluids, hydrocarbons, or combinations thereof. Particular examples of a suitable fluid include silicon oil, paraffin oil, petroleum-based oils, brake fluid (glycol-ether-based fluids, mineral-based oils, and/or silicon-based fluids), transmission fluid, synthetic fluids, or combinations thereof.
In an embodiment, the metering check valve 210 may be configured so as to allow or disallow a route of fluid communication via the flowbore 143 of the metering check valve assembly 141, for example, dependent upon the direction of fluid movement through the flowbore 143. Also, in an embodiment, the metering check valve 210 may be configured to allow fluid communication, in a given direction, at a predetermined rate. In such an embodiment, the metering check valve 210 may be joined, incorporated, and/or integrated within the metering check valve assembly 140 (e.g., within the flowbore 143 of the collar 141) via any suitable connection or coupling, for example, via an internally and/or externally threaded interface.
Referring to
In an embodiment, the valve member 203 may be slidably and concentrically positioned within the valve body 200. For example, in an embodiment, at least a portion of the cylindrical valve member surface 203c may be slidably fitted within at least a portion of the valve bore surface 200b of the valve body 200.
In an embodiment, the valve member 203 may be moveable with respect to the valve body 200, for example, from a first position to a second position with respect to the valve body 200. For example, in an embodiment, the valve member 203 may be positioned so as to allow or disallow a route of fluid communication via the inlet port 201 and the outlet port 205, dependent upon the position of the valve member 203 relative to the valve body 200. In such an embodiment, in the first position, the valve member 203 engages (e.g., sealingly engages, for example, via a ball 203e located within the first valve member orthogonal surface 203a) the seat 202 of the valve body 200, for example, and blocks fluid communication from the inlet port 201 of the valve body 200 to the outlet port 205. Also, in such an embodiment, in the second position, the valve member 203 does not block fluid communication from the inlet port 201 of the valve body 200 to the outlet port 205 and, thereby allows fluid communication, for example, fluid may flow from the second chamber 138b to the first chamber 138a via the inlet port 201.
Additionally, in an embodiment, the biasing member 204 (e.g., a spring) may be generally configured to bias the valve member 203 in the direction of the first position. For example, in the embodiment of
In an embodiment, the valve member 203 may be configured to transition from the first position to the second position. For example, in an embodiment, the valve member 203 may be configured to transition from the first position to the second position upon an application of a fluid pressure (e.g., a differential, hydraulic pressure) of at least a biasing member compression threshold to the inlet port 201 side of the flowbore 143. In such an embodiment, the biasing member compression threshold may be the force required to overcome a biasing force by the biasing member 204, for example, so as to compress (or further compress) the biasing member 204. For example, the metering check valve 210 may be configured such that, upon the application of a fluid pressure to the inlet port 201 sufficient to compress the biasing member 204, the valve member 203 will unseat from the seat 202 of the valve body 200 in move toward the second position, thereby allowing fluid to be communicated from the inlet port 201 to the outlet port 205, for example, via the flowbores 203d of the valve member 203 and/or the flowpath 206 through the valve body 200. As such, the metering check valve 210 may be configured such that fluid may only be communicated therethrough from the inlet port 201 in the direction of the outlet port 205. Also, the valve member 203 may be configured so as to not transition from the first position to the second upon the upon the application of fluid pressure to the outlet port 205 side of the flow bore 143.
In an embodiment, the metering check valve 210 may be configured to allow fluid communication (e.g., upon fluid communication from the inlet port 201 in the direction of the outlet port 205) at a predetermined rate. For example, the metering check valve 210 (e.g., the inlet port, the outlet port 205, the central flowpath 206, or combinations thereof) may comprise a flow-rate altering device, for example, a fluid meter, a fluidic diode, a fluidic restrictor, an orifice, a nozzle or the like. In an embodiment, such a flow-rate altering device may be sized to allow a given flow-rate of fluid, and thereby provide a desired time or delay associated with flow of fluid from the second chamber portion 138b to the first chamber portion 138a and, as such, the movement of the sliding sleeve 126. Suitable fluid flow-rate control devices are commercially available from The Lee Company of Westbrook, Conn. and include, but are not limited to, a precision microhydraulics fluid restrictor, a micro-dispensing valve, or fluid jets such as the Lee Visco Jet, the Lee Micro Jet, or the Lee Jeva Jet products. Additionally, in such an embodiment, a flow-rate control device may similarly be included within the flowbore 143 through the collar, for example, so as to similarly control the rate of fluid movement from the second chamber portion 138b to the first chamber portion 138a. Examples of suitable metering check valves 210 are commercially available as the Lee Chek line of check valves from The Lee Company.
In an embodiment, a wellbore servicing method utilizing the IPTV 100 and/or a wellbore servicing system comprising an IPTV 100 is disclosed herein. In an embodiment, a wellbore servicing method may generally comprise the steps of positioning the casing string 150 comprising a IPTV 100 within a wellbore 114 that penetrates the subterranean formation 102, and pressure testing the casing string 150 (which may comprise applying a fluid pressure of at least an upper threshold within the casing string 150 and maintaining fluid pressure within the casing string 150 for a predetermined duration of time, as will be disclosed herein). In an additional embodiment, a wellbore servicing method may further comprise one or more of the steps of communicating a fluid via the IPTV 100, actuating a wellbore servicing tool (e.g., a wellbore stimulation tool), communicating a wellbore servicing fluid via the wellbore servicing tool, and/or producing a formation fluid from the formation.
Referring to
In the embodiment, the IPTV 100 is introduced and/or positioned within a wellbore 114 (e.g., incorporated within the casing string 150) in a first configuration, for example, as shown in
In an embodiment, positioning the IPTV 100 may comprise securing the casing string with respect to the formation. For example, in the embodiment of
In an embodiment, the wellbore servicing method comprises pressure testing the casing string 150. For example, in embodiment, during the performance of such a pressure test, a pressure, for example, a pressure of at least a threshold pressure, may be applied to the casing string 150 for a given, predetermined duration. Such a pressure test may be employed to assess the integrity of the casing string 150 and/or components incorporated therein, for example, ensuring that the casing string 150 will withstand such pressures. In an embodiment, pressure testing the casing string 150 may generally comprise applying a hydraulic to/within the casing string 150 and maintaining the application of fluid pressure within the casing string 150 for a predetermined duration.
In an embodiment (for example, in the performance of a pressure test), the wellbore servicing method comprises applying a hydraulic fluid pressure within the casing string 150, for example, by pumping a fluid into the casing via one or more pumps typically located at the surface, such that the pressure within the casing string 150 reaches an upper threshold.
In an embodiment, the pressure applied to the casing string 150, for at least a portion of a predetermined duration over which the pressure is applied, as will be disclosed herein, may be of at least a pressure threshold. For example, the threshold pressure may be at least about 8,000 p.s.i., alternatively, at least about 10,000 p.s.i., alternatively, at least about 12,000 p.s.i., alternatively, at least about 15,000 p.s.i., alternatively, at least about 18,000 p.s.i., alternatively, at least about 20,000 p.s.i., alternatively, any suitable pressure about equal to or less than the pressure at which the casing string 150 is rated.
In an embodiment, the application of such a hydraulic fluid pressure (e.g., applied for a predetermined duration) may be effective to transition the sliding sleeve 126 from the first position to the second position. For example, the hydraulic fluid pressure may be applied through the axial flowbore 124, including to the sliding sleeve 126 of the IPTV 100. As disclosed herein, the application of a fluid pressure to the IPTV 100 may yield a force applied to the sliding sleeve 126 in the direction of the second position, for example, because of the differential between the force applied to the sliding sleeve 126 in the direction toward the second position (e.g., an downward force) and the force applied to the sliding sleeve in the direction away from the second position (e.g., a upward force).
In an embodiment, the IPTV 200 may be configured such that the application of a hydraulic fluid pressure of a predetermined magnitude (e.g., the pressure threshold) may exert a force in the direction of the second position sufficient to shear the one or more shear pins 134, for example, thereby causing the sliding sleeve 126 to begin to move in the direction of the second position (e.g., as controlled by the fluid delay system). Additionally or alternatively, in an embodiment, application of fluid pressure to the IPTV 100 to may be sufficient to cause the hydraulic fluid within the second chamber portion 138b to flow through the flowbore 143 of the metering check valve assembly 141. In such an embodiment, the hydraulic fluid within the inlet port 201 may exert a force onto the valve member 203 sufficient to transition the valve member 203 from first position to the second position. For example, as the sliding sleeve 126 begins to move in the direction of the second position, the hydraulic fluid within the second chamber portion 138 becomes compressed and, thereby, exerts a force against the valve member 203, causing the metering check valve 210 to open and flow to move from the second chamber portion 138b to the first chamber portion 138a via the flowbore 143. In an embodiment, the force (e.g., the fluid pressure) necessary to shear the one or more shear pins 134 may be about the same as the force necessary to cause the hydraulic fluid to move (or continue to move) through the metering check valve 210 (e.g., to open the metering check valve, as disclosed herein). Alternatively, the force (e.g., the fluid pressure) necessary to shear the one or more shear pins 134 may be greater than, alternatively, less than, the force necessary to cause the hydraulic fluid to continue to move through the metering check valve 210. In such embodiments, the force (e.g., fluid pressure) applied to the sliding sleeve 126 to transition to the second position may vary over the travel of the sliding sleeve 126.
Also, in an embodiment (for example, in the performance of a pressure test), the wellbore servicing method comprises maintaining the application of fluid pressure to the casing string 150. In an embodiment, the pressure may applied to the casing string 150 over a predetermined duration, as will be disclosed herein. For example, the predetermined duration may be from about 5 minutes to about 120 minutes, alternatively, from about 15 minutes to about 60 minutes, alternatively, from about 20 minutes to about 40 minutes, alternatively of about 30 minutes, alternatively, any suitable duration. For example, in the performance of a pressure test, the pressure applied to the casing string 150 may be maintained for a sufficient duration to ensure the integrity of the casing string 150 and/or any components incorporated therein, as disclosed herein. In an embodiment, the duration over which the pressure is applied to the casing string 150 may also be sufficient to allow the sliding sleeve 126 to transition from the first position to the second position. For example, the IPTV 100 may be configured such that the sliding sleeve 126 will reach the second position, as will be disclosed herein, substantially contemporaneously with the end of the predetermined duration. Also, the predetermined duration may be configured for any suitable duration via the manipulation of one or more of the size of the second chamber portion 138b; the size, number, and/or configuration of the metering check valve that is utilized (e.g., the rate at which the metering check valve is configured to allow fluid communication); the characteristics of the fluid (e.g., the hydraulic fluid) that is retained within the second chamber portion 138b; or combinations thereof.
In an embodiment, as the fluid pressure continues to be applied to the sliding sleeve 126, the hydraulic fluid continues to move through the flowbore 143 of the collar 141, thereby allowing the sliding sleeve 126 to move (e.g., slide) in the direction of the second position until the collar 141 reaches the third shoulder 120g of the housing 120. Upon reaching and/or passing the third shoulder 120g, the third outer cylindrical surface 141c of the collar 141 ceases to sealingly engage the second bore surface 120b of the housing 120, for example, because the collar 141 becomes longitudinally aligned with the third bore surface 120c of the housing 120 and does not sealingly engage the third bore surface 120c. In such an embodiment, the hydraulic fluid is allowed to move relatively freely from the second chamber portion 138b to the first chamber portion 138a, thereby allowing the sliding sleeve 126 to move toward the second position with the application of relatively little force. In an alternative embodiment, the third bore surface 120c, rather than having a greater diameter, may comprise one or more longitudinal grooves, similarly allowing fluid to bypass the flowbore 143 of the collar 141.
The sliding sleeve 126 moves toward the second position, for example, until the second surface 141b of the metering check valve assembly 141 engages the fourth shoulder 120h of the housing 120, thereby preventing or restricting the sliding sleeve 126 from further movement. Additionally, in an embodiment the hydraulic fluid within the first chamber 138a may apply a force onto the metering check valve assembly 141 restricting and/or preventing the sliding sleeve 126 from moving fully to the first position. Thus, the sliding sleeve 126 is retained in the second position in which the ports 122 of the housing 120 are no longer blocked, thereby allowing fluid communication out of the casing string 150 (e.g., to the wellbore 114, the subterranean formation 102, or both) via the ports 122 of the housing 120.
In an embodiment, the duration over which the pressure is applied to the casing string 150 need not be continuous. For example, the application of pressure (e.g., during the performance of a pressure test) may comprise one or more interruptions. For example, during the performance of a pressure test, an interruption in the pressure applied to the casing string 150 may result intentionally or unintentionally. In such an embodiment, the predetermined duration of time may comprise one or more subintervals of time (e.g., a first subinterval, a second subinterval). For example, in an embodiment, to transition the sliding sleeve 126 to the second position, the fluid pressure may be applied to the casing string 150 in two or more intervals (for example, a first subinterval of about five minutes and a second subinterval of about twenty-five minutes). In such an embodiment, the second subinterval may occur following one or more periods of time when the fluid pressure applied to the casing string 150 falls below the threshold pressure, for example, a period of time when the applied fluid pressure to the casing string 150 is reduced below the upper threshold pressure to inspect and/or repair a portion of the casing string 150. For example, it is not necessary that the fluid pressure of at least the pressure threshold be applied continuously for the predetermined duration; the predetermined duration may be interrupted (e.g., the pressure may fall below the pressure threshold) on one or more occasions while the sliding sleeve 126 transitions toward the second position. For example, in an embodiment where the fluid pressure within the casing string falls below the threshold pressure, the metering check valve 210 may close and the sliding sleeve 126 will cease to move in the direction of the second position. Upon resuming the pressure test (e.g., upon reapplying a fluid pressure, as disclosed herein), the metering check valve 210 may reopen and fluid may continue to move through the metering check valve 210, as previously disclosed herein, thereby allowing the sliding sleeve 126 to continue to move in the direction of the second position.
In an embodiment, following the transitioning of the sliding sleeve 126 into the second position, fluid may be allowed to escape the axial flowbore 115 of the casing 150 and the axial flowbore 124 of the IPTV 100 via the ports 122 of the IPTV 100.
In an embodiment, communicating a fluid via the IPTV 100 may comprise communicating a wellbore servicing fluid through the ports 122, for example, for the purposes of performing a formation stimulation operation. Nonlimiting examples of a suitable wellbore servicing fluid include but are not limited to a fracturing fluid, a perforating or hydrajetting fluid, an acidizing fluid, the like, or combinations thereof. The wellbore servicing fluid may be communicated at a suitable rate and pressure for a suitable duration. For example, the wellbore servicing fluid may be communicated at a rate and/or pressure sufficient to initiate or extend a fluid pathway (e.g., a perforation or fracture) within the subterranean formation 102 and/or a zone thereof.
Additionally or alternatively, in an embodiment, communicating a fluid via the IPTV 100 may comprise allowing fluid to escape from the casing string 150, for example, so as to allow an obturating member to be introduced within the casing string 150 and communicated therethrough (e.g., via forward fluid flow through the casing and out of the opened portion of the IPTV 100. For example, following a pressure test, an obturating member may be communicated through at least a portion of the casing string 150 so as to engage a suitable obturating member retainer (e.g., a seat) within a wellbore servicing tool incorporated within the casing string 150, for example, thereby allowing actuation of such a wellbore servicing tool (e.g., opening of one or more ports, sliding sleeves, windows, etc., within a fracturing and/or perforating tool) for the performance of a formation servicing operation, for example, a formation stimulation operation, such as a fracturing, perforating, acidizing, or like stimulation operation.
In an embodiment, a wellbore servicing operation may further comprise communicating a wellbore servicing fluid, for example, for the purposes of performing a formation stimulation operation via one or more wellbore servicing tools incorporated within the casing string. Additionally or alternatively, in an embodiment, the wellbore servicing method may further comprise producing a formation fluid (for example, a hydrocarbon, such as oil and/or gas) from the subterranean formation 102 via the wellbore 114.
In an embodiment, an IPTV 100, a system comprising an IPTV 100, and/or a wellbore servicing method employing such a system and/or an IPTV 100, as disclosed herein or in some portion thereof, may be advantageously employed in pressure testing a casing string. For example, in an embodiment, an IPTV like IPTV 100 enables a pressure testing of a casing string 150 to be halted (e.g., allowing the applied pressure to be reduced to inspect and/or repair the casing string 150) and later resumed (e.g., increasing the applied pressure following inspection and/or repairs). Conventional methods do not allow a pressure test to be resumed.
Additionally, in an embodiment, an IPTV like IPTV 100 enables a casing string to be safely pressurized (e.g., tested) at a desired pressure, but does not require that such test pressure be exceeded following the pressure test in order to transition open a valve. For example, because IPTV 100 can be configured to transitioned from the first configuration to the second configuration, as disclosed herein, upon any suitable pressure and because the IPTV 100 does not allow fluid communication until the IPTV 100 has maintained the suitable pressure for a predetermined duration of time, a IPTV as disclosed herein may be opened without exceeding the maximum value of the pressure test, for example, as is conventionally necessary.
As may be appreciated by one of skill in the art, conventional methods of providing fluid communication from the casing to the surrounding wellbore and/or formation following a pressure testing a casing string require, following the pressure test, over-pressuring a casing string to shear one or more shear pins and shift a sleeve or otherwise open fluid ports for fluid flow and thereby enable fluid communication from the axial flowbore of the casing string to the wellbore formation. As such, conventional tools, systems, and/or methods do not provide a way to ensure the opening of one or more ports without the use of pressure levels which would generally exceed the maximal pressures used during pressure testing. Therefore, the methods disclosed herein provide a means by which pressure testing of a casing string can be performed only requiring pressure levels within the standard pressure testing levels.
The following are nonlimiting, specific embodiments in accordance with the present disclosure:
A first embodiment, which is a wellbore servicing system comprising:
A second embodiment, which is the wellbore servicing system of the first embodiment, wherein the predetermined pressure comprises a pressure threshold.
A third embodiment, which is the wellbore servicing system of the second embodiment, wherein the predetermined pressure varies over the predetermined duration.
A fourth embodiment, which is the wellbore servicing system of one of the first through the third embodiments, wherein the pressure testing valve comprises one or more frangible members.
A fifth embodiment, which is the wellbore servicing system of the fourth embodiment, wherein the one or more frangible members are configured to restrain the sliding sleeve in the first position.
A sixth embodiment, which is the wellbore servicing system of one of the first through the fifth embodiments, where the pressure testing valve comprises a fluid chamber, wherein the fluid chamber is not fluidicly exposed to the axial flowbore.
A seventh embodiment, which is the wellbore servicing system of the sixth embodiment, wherein the sliding sleeve comprises a collar, wherein the collar is configured to divide the fluid chamber into a first chamber portion and a second chamber portion across at least a first portion of the sliding sleeve stroke.
An eighth embodiment, which is the wellbore servicing system of the seventh embodiment, wherein the collar comprises a check valve, wherein the check valve is configured to control fluid communication from the first chamber portion to the second chamber portion over at least the first portion of the sliding sleeve stroke.
A ninth embodiment, which is the wellbore servicing system of one of the second through the third embodiments, wherein the pressure threshold is at least about 8,000 p.s.i.
A tenth embodiment, which is the wellbore servicing system of one of the second through the third embodiments, wherein the pressure threshold is at least about 10,000 p.s.i.
An eleventh embodiment, which is the wellbore servicing system of the third embodiment, wherein the predetermined duration is from about 15 minutes to about 60 minutes.
A twelfth embodiment, which is the wellbore servicing system of the third embodiment, wherein the predetermined duration comprises an accumulation of one or more subintervals of time.
A thirteenth embodiment, which is a wellbore servicing method comprising:
A fourteenth embodiment, which is the method of the thirteenth embodiment, wherein the sliding sleeve is initially retained by one or more frangible members prior to the application of fluid pressure of at least the upper threshold, wherein the application of fluid pressure of at least the pressure threshold causes the one or more frangible members to fail.
A fifteenth embodiment, which is the method of one of the thirteenth through the fourteenth embodiments, wherein the pressure threshold is at least about 8,000 p.s.i.
A sixteenth embodiment, which is the method of one of the thirteenth through the fifteenth embodiments, wherein the pressure threshold is at least about 10,000 p.s.i.
A seventeenth embodiment, which is the method of one of the thirteenth through the sixteenth embodiments, wherein the predetermined duration is from about 15 minutes to about 60 minutes.
An eighteenth embodiment, which is the method of one of the thirteenth through the seventeenth embodiments, further comprising communicating a fluid via the one or more ports.
A nineteenth embodiment, which is a wellbore servicing method comprising:
A twentieth embodiment, which is a wellbore servicing method comprising:
A twenty-first embodiment, which is the method of the twentieth embodiment, wherein flowing the fluid down the tubing string further comprises flowing an obturating member down the tubing string, landing the obturating member on a landing structure associated with a wellbore tool, and applying a hydraulic force to the wellbore tool via the landed obturating member to configure the wellbore tool to perform a wellbore service.
A twenty-second embodiment, which is the method of one of the twentieth through the twenty-first embodiments, wherein the obturating member is a ball or dart, the landing structure is a seat configured to receive the ball or dart, the wellbore servicing tool is a fracturing or perforating tool, and the wellbore service is a fracturing or perforating service.
A twenty-third embodiment, which is the method of one of the twentieth through the twenty-second embodiments, wherein flowing the fluid down the tubing string further comprises communicating a wellbore servicing fluid at a rate and/or pressure sufficient to initiate and/or extend a fluid pathway with the formation.
A twenty-fourth embodiment, which is a pressure testing valve comprising:
A twenty-fifth embodiment, which is the pressure testing valve of the twenty-fourth embodiment, wherein the fluid delay system comprises:
A twenty-sixth embodiment, which is the pressure testing valve of the twenty-fifth embodiment, wherein the metering check valve is configured to allow fluid movement from the second chamber to the first chamber and to not allow fluid communication from the first chamber to the second chamber.
A twenty-seventh embodiment, which is the pressure testing valve of one of the twenty-fifth through the twenty sixth embodiments, wherein the metering check valve is generally disposed within a collar extending circumferentially around the sliding sleeve.
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, Rl, 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=Rl+k*(Ru−Rl), 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.
