• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
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  • 优先权
    • 专利摘要:
    The present disclosure relates to a method of detecting the presence of a downhole fluid at a particular position in a wellbore (18, 102, 202), the method comprising pumping an activating fluid (56) into a wellbore (18, 102, 202); contacting a flow control device (40, 100, 200, 400, 410) in a column casing string with the activating fluid (56), the flow control device (40, 100, 200). , 400, 410) comprising at least one inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216); activating the at least one element capable of inflating in the flow control device (40, 100, 200, 400, 410); blocking fluids or regulating the flow of fluids entering or exiting the casing with the activated flow control device; allowing a change of pressure; and detecting the change in pressure. The present disclosure also relates to apparatus comprising a drill string in a wellbore (18, 102, 202) and a flow control device (40, 100, 200, 400, 410) in the tubular string train, wherein the flow control device comprises at least one inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216), wherein upon activation, the at least one swellable member swells and tightly seals, partially or completely, the flow region of the flow control device (40, 100, 200, 400, 410).
    公开号:FR3041682A1
    申请号:FR1657897
    申请日:2016-08-24
    公开日:2017-03-31
    发明作者:Jimenez Walmy Cuello；John P Singh；Xueyu Pang；Marcos Aurelio Jaramillo；Krishna M Ravi；Thomas Jason Pisklak
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    CONTEXT
    In primary cementing operations performed in oil and gas wells, a hydraulic cement composition is placed between the walls of the wellbore and the outside of a drill string, such as a casing string, which is placed inside the wellbore. The cement composition is allowed to set in the annulus, thereby forming an annular sheath of impermeable cement substantially hardened therein. The cement sheath physically supports and positions the shaft in the wellbore and binds the shaft to the walls of the wellbore thereby preventing unwanted migration of fluids between zones or formations penetrated by the wellbore.
    A primary cementing process involves pumping the cementitious composition down through the casing and upwardly through the annulus. In this process, the volume of cement required to fill the annulus must be calculated. Once the calculated volume of cement has been pumped into the casing, a cement plug is placed in the casing. A displacement fluid (eg, drilling mud) is pumped behind the cement plug so that the cement is forced into and out of the annulus from the far end of the drill string. casing to the surface or another desired depth. When the cement plug reaches a floating shoe placed near the far end of the casing, the cement must have filled the predetermined volume or the total volume of the annular space. At this point, the cement is allowed to dry in the annular space, in the cured, substantially impermeable mass. As the drilling industry continues to evolve into harsher environments with high pressures and high temperatures as a result of ultra deep water, mature field, and unconventional hydrocarbon / gas wells, Pore pressure gradients of formation and fracture are reduced. As a result, it is found that, due to the high pressure at which the cement is to be pumped, at a pressure higher than the hydrostatic pressure of the cement column in the annular space to which is added the frictional pressure Equivalent Circulating Density = Phydrostatic + Pfriction), a fluid emanating from the cementitious composition may leak into a low pressure area traversed by the wellbore, particularly in locations where the margins of pore pressure / fracture gradients are extremely small. When such a leak occurs, the remainder of the cement composition near this low pressure zone is not sufficient to provide optimum zonal isolation to the required area. It follows that remediation cementing operations, commonly referred to as lateral injection cementation, must be used to place cement in the remainder of the annulus.
    Therefore, prior art attempts have been made to avoid the problems associated with fluid leakage in low pressure areas during cementing operations, particularly in the case of reduced margins. One method of preventing such problems is called reverse circulation cementation, in which the cement composition is pumped directly into the annulus. When this approach is used, the pressure required to pump cement to the far end of the annulus is significantly less than that required in conventional cementing operations. As a result, the pumping pressure of the cement, and hence the EDC, is significantly reduced which, in turn, decreases the probability of fracturing the formation, and the fact of having significant losses before the entire annular space or a planned area are filled with cement is greatly reduced.
    It has been determined, however, that with reverse circulation cementation, it is necessary to identify when the cement begins to penetrate into the far end of the casing and reaches the desired depth inside the casing to leave the desired shoe track length so that the cement pumps can be stopped. Continuing to pump the cement into the annulus after the cement has reached the desired position after passing through the far end of the casing, unwanted amounts of cement are forced into the casing which, in turn, may require additional stripping times.
    A method used to identify when the cement has reached the far end of the annulus is to lower a neutron density measuring tool down the casing on a power line. The neutron density measuring tool monitors the density to a predetermined depth in the formation. When the cement begins to replace the drilling mud in the annular space adjacent to the neutron density measuring tool, the neutron density measuring tool detects the change in density and indicates to the surface that it is time to stop pumping more cement into the annulus. Another method used to identify when the cement has reached the far end of the annulus is to lower a resistivity measuring tool and a wireless telemetry system down the casing on a cable line. The resistivity measuring tool monitors the resistivity of the fluid in the casing so that when the cement begins to replace the drilling mud in the casing a wireless signal is sent to the surface to indicate that it is time to stop pumping more cement into the annulus. I! It has been determined, however, that the cost of using such retrievable tool systems is prohibitive. In fact, a large number of neutron density measuring tools and resistivity measuring tools have been ruined during such operations as a result of the cement entering the far end of the casing and coming into contact with it. with these tools.
    Therefore, a need has arisen for a system and method adapted to cement the annulus between the wellbore and the casing, which does not require pumping the cement at pressures that allow leaks in low areas. pressure, especially in operations where margins are reduced. There is also a need for a suitable system and process for identifying when to stop pumping more cement into the wellbore. In addition, a need has arisen for a system and method that does not require the use of expensive equipment, including tools that must be retrieved from the well once the cementing operation is completed.
    BRIEF DESCRIPTION OF THE DRAWINGS
    The following figures are included to illustrate certain aspects of the present invention and should not be considered as exclusive embodiments. The subject matter described in this disclosure may be subject to significant modifications, alterations, and the like in terms of form and function, as will be apparent to those skilled in the art knowing the advantages of the present disclosure.
    Fig. 1 is a flow chart of an embodiment of the present disclosure.
    Fig. 2 is a schematic illustration of an onshore oil or gas drilling platform using a system for controlling an underground valve to terminate a reverse circulation cementing or cementing operation of the present invention.
    Figure 3 is a schematic illustration of an automatically operated underground valve.
    Figs. 4A, 4B, and 4C illustrate the control mechanism of the automatically operated underground valve under various triggering conditions.
    Figures 5A and 5B illustrate the change in surface pressure and the swelling thickness of the elements capable of inflating a valve upon activation.
    Figs. 6A and 6B illustrate a reverse circulation cementing operation according to embodiments of the present disclosure.
    Figs. 7A and 7B illustrate a reverse circulation cementation operation comprising an activating fluid according to embodiments of the present disclosure.
    Fig. 8 is a flowchart of a reverse circulation cementing operation according to embodiments of the present disclosure.
    Figs. 9A, 9B and 9C are illustrations of flow control devices according to embodiments of the present disclosure.
    DETAILED DESCRIPTION
    The present invention relates to the detection of the presence of a particular material or fluid downhole, as well as the actions taken during detection. In particular, the present invention relates to the use of materials capable of swelling to detect and react to the presence of certain downhole materials.
    The present invention provides systems and methods for controlling an underground flow control device. Although the systems and methods are described as being useful for operating valves during a reverse circulation cementing operation, those skilled in the art will readily understand that the systems and methods described herein are also ideally suited for controlling valves during other well operations and to control downhole equipment other than valves.
    Fig. 1 is a flowchart illustrating a procedure for detecting the position of a downhole fluid in a wellbore according to an embodiment of the present disclosure. In the procedure, an activating fluid is pumped into the wellbore 2. The activating fluid comes into contact with a flow control device in a columnar tubing string 3, and activates an element capable of inflating in the regulating device 4. The swelling of the element blocks or regulates the fluid entering or exiting the casing 5, and can increase the pressure due to the swelling reaction of the flow control device to the activating fluid 6. The surface pressure is monitored surface 7. If the surface pressure does not increase, the surface pressure then continues to be monitored 7. If the surface pressure increases, this indicates that the downhole fluid has been detected at a position particular 8.
    Devices without electronics are an advantage of the methods and devices of the present disclosure. In a large number of embodiments, the devices and methods do not require wired bottomhole communication, or any other type of downhole communication, which makes them particularly suitable for downhole fluid detection applications. The benefits may reduce the time spent sending and / or retrieving the cable line equipment from the downhole. Another advantage is that the devices and methods need not depend on the reliability of the electronic components in the downhole environment.
    One embodiment of the present disclosure relates to a method of detecting the presence of a downhole fluid at a particular position in a wellbore, the method comprising pumping an activating fluid into a wellbore comprising a column casing string; contacting a flow control device in the column casing string with the activating fluid, the flow control device being placed in the column casing string, and the flow control device comprising at least a swellable member, wherein upon activation, the at least one swellable member swells and seals, partially or completely, the flow region of the flow control device, thereby regulating at least one one of a flow rate, a pressure, and a combination of these elements; activating at least one element capable of inflating in the flow control device, thereby creating an activated flow control device; blocking fluids or regulating the flow of fluids entering or exiting the casing with the activated flow control device; allowing a change of pressure; and detecting the change in pressure. In one embodiment, the flow control device is a valve. In one embodiment, the at least one swellable element comprises at least one of pH sensitive materials, hydrogels, polyelectrolytes, and combinations thereof. Activation may include at least one trigger selected from pH change, oxidation and reduction, solvent exchange, ionic strength change, oil based change, light irradiation, temperature change, physical deformation, magnetic field application, electric field application, microwave irradiation, temperature, pressure gradients, and combinations thereof. In one embodiment, the method further includes a plurality of flow control devices at different positions, resulting in a series of pressure pulses that are communicated to the surface as a result of a plurality of pressure events created. by the plurality of swelling of the plurality of flow control devices. In another embodiment, the flow control device is a mass-stem valve or shoe valve, or any other type of valve located at any desired position within the casing string. In one embodiment, the valve inflatable member comprises a material capable of swelling on at least one of the valve head, the valve stem, and combinations thereof. The method may further include deactivating the swellable element. In another embodiment, the deactivation comprises pumping a fluid into the wellbore which causes the contraction of the inflatable member.
    One embodiment of the present disclosure relates to a wellbore cementation method, including pumping an activating fluid through an annulus between a drill string and the wellbore or through the tubing string. column ; pumping at least one of a cement slurry, a resin-based fluid, and combinations thereof, through an annulus between a drill string and the wellbore or through the column casing string; contacting a flow control device in the column casing string with the activating fluid, the flow control device comprising at least one element capable of inflating, wherein upon activation, the at least one swellable member swells and seals, partially or completely, the flow area of the flow control device, thereby controlling at least one of the flow rate, a pressure, and a combination of these elements; activating the at least one element capable of inflating in the flow control device, thereby creating an activated flow control device; and blocking or regulating the activating fluid with the activated flow control device. In one embodiment, the cement slurry and the activating fluid are pumped through the column casing string, and the at least one of a cement slurry and a resin fluid is pumped prior to activating fluid. The method may further include placing a cement plug in the tubing between pumping the at least one of a cement slurry and a resin-based fluid and pumping the activating fluid. In another embodiment, the at least one of a cement slurry and a resin-based fluid and the activating fluid are pumped through the annulus between the drill string and the wellbore, and the activating fluid is pumped before the at least one of a cement slurry and a resin-based fluid. In one embodiment, the activating fluid is also at least one of a cement slurry and a resin-based fluid. In one embodiment, the flow control device is a valve. In one embodiment, the at least one swellable element comprises at least one of pH sensitive materials, hydrogels, polyelectrolytes, and combinations thereof. Activation may include at least one trigger selected from pH change, oxidation and reduction, solvent exchange, ionic strength change, oil based change, light irradiation, temperature change, physical deformation, magnetic field application, electric field application, microwave irradiation, temperature, pressure gradients, and combinations thereof. In one embodiment, the method further includes allowing the pressure to change and detecting the change in pressure. In one embodiment, the detection includes monitoring pressure increases of the surface pressure. The method may further include a plurality of flow control devices at different positions, resulting in a series of pressure pulses that are communicated to the surface as a result of a plurality of pressure events created by the plurality of devices. flow control device comprising a plurality of swelling elements. In one embodiment, the method further comprises adjusting the flow rate of the at least one of a cement slurry and a resin-based fluid when the surface pressure increases rapidly or a series of Pressure pulses are imparted to the surface. The method may further comprise one of stopping the flow of the at least one of a slurry of cement and a resin-based fluid, adjusting the flow rate of Tau at least one of a slurry cement and a resin-based fluid, and combinations of these steps. In another embodiment, the method further comprises pumping a displacement fluid through the annulus behind the at least one of a cement slurry and a resin-based fluid before the at least one of a cement slurry and a resin-based fluid has contacted the valve. In some embodiments, the valve may be a mass-stem valve or a shoe valve, which may be placed at any desired position within the casing string. The element capable of inflating the valve comprises a material capable of swelling on at least one of the valve head, the tail of the valve, and combinations thereof. The at least one of a cement slurry and a resin-based fluid comprises at least one of an additive, a tracer, and combinations of these elements, which activates the at least one element capable of to inflate. In one embodiment, the method further includes deactivating the inflatable member. In an exemplary embodiment, deactivation includes pumping a fluid down the casing or annulus that causes contraction of the inflatable member.
    An embodiment of the present disclosure relates to an apparatus for blocking or regulating fluid flow in a wellbore, the apparatus comprising: a drill string in a wellbore; and a flow control device in the column casing string, wherein the valve comprises at least one element capable of inflating, wherein upon activation activation, the at least one inflatable element inflates and hermetically, partially or completely sealing the flow area of the flow control device, thereby blocking or regulating the flow of fluids into or out of the drill string.
    In some embodiments, the flow control device is a valve. The at least one swellable element comprises at least one of pH sensitive materials, hydrogels, polyelectrolytes and combinations thereof. The activation trigger may comprise at least one trigger selected from pH change, oxidation and reduction, solvent exchange, ionic strength change, oil based change, light irradiation, temperature change. physical deformation, magnetic field application, electric field application, microwave irradiation, temperature, pressure gradients, and combinations thereof. In some embodiments, the valve may be a mass-stem valve or a shoe valve. The element capable of inflating the valve comprises a material capable of swelling on at least one of the valve head, the tail of the valve, and combinations thereof.
    A system for generating a pressure peak or pressure pulses when a downhole fluid is present at a particular position in a wellbore comprises: an apparatus comprising: a drill string in a wellbore; and a flow control device in the column casing string near the bottom of the wellbore, wherein the valve comprises at least one element capable of inflating, wherein upon activation triggering, the at least one swellable member swells and tightly seals, partially or completely, the flow region of the flow control device, thereby blocking or regulating the flow of fluids into or out of the drill string; pumping an activating fluid into the wellbore; pumping a downhole fluid into the wellbore; contacting the flow control device in the column casing string with the activating fluid; activate the at least one element capable of inflating in the flow control device, thereby creating an activated flow control device; blocking or regulating the flow of downhole fluids or activating fluids entering or exiting the casing with the activated flow control device; and allowing the pressure to cause at least one tip or at least one pulse. The system may further include detecting the tip or pressure pulse on the surface of the wellbore. In one embodiment, detecting the tip or pressure pulse indicates that a downhole fluid is present near a certain downhole position. In one embodiment, the indication that the downhole fluid is present near a certain downhole position is performed without downhole wired communications. As shown in Fig. 2, an onshore oil or gas drilling platform using a system for controlling an underground valve to terminate a reverse circulation cementing or grouting operation of the present invention is schematically illustrated. and generally designated at 10. A similar platform may also be used for offshore drilling. The platform 12 is centered on an underground oil or gas formation 14 placed below the surface of the earth. Drill 18 extends through the various land strata comprising the formation 14. The wellbore 18 is lined with a casing train 20. The casing 20 includes a valve 22 which is placed near the far end of the casing. 20 or any other desired position. The valve 22 is used to selectively allow and prevent the flow of fluids therethrough. For example, during a reverse circulation cementing operation, the valve 22 remains open while a drilling fluid 24 is forced from an annular space 26 into the far end of the casing 20 when cement 28 is pumped, via a cement pump 30, in the proximal end of the annular space 26. When the anterior edge of the cement 28 reaches the far end of the casing 20 or the desired position, the valve 22 closes to prevent an excessive amount of cement 28 circulates within casing 20. Thereafter, cement 28 is allowed to settle in annular space 26 so as to form a substantially impermeable cured mass which physically supports and positions casing 20 in the wellbore 18 and binds the casing 20 to the walls of the wellbore 18.
    The platform 12 includes a working bridge 32 which supports a derrick 34. The derrick 34 supports a hoist 36, for lifting and lowering rod trains, the casing 20 for example. A pump 30 on the work deck 32 is of conventional construction and of the type capable of pumping a variety of fluids into the well. The pump 30 comprises a pressure measuring device which provides a pressure reading at the discharge port of the pump.
    In cementing operations, as a general rule, some of the cement is left in the casing (this is known as a shoe track), typically 80 ft (two casing junctions), but this may vary depending on conditions and software simulations. This can ensure that the annulus does not contain any contaminated cement residue, when maximum isolation is required. The detection apparatus of the present disclosure is sufficiently flexible to be placed at the desired casing junction, so that the length of the desired hoof track is left inside the casing. If the detection is not done correctly or is not done at all, the shoe track may be too long and then require additional drilling time, which is too short, which may compromise potentially the integrity of the cement at the lowest depths.
    Figure 3 illustrates a valve 40 according to embodiments of the present disclosure. The valve 40 is placed on a drill collar or shoe 42. The valve assembly 44 may comprise a spring 46, a first inflatable element 48, and optionally a second inflation capable element 50. In one embodiment, the first inflatable member 48 has a resting thickness 52 of S0 prior to exposure to an activating fluid, an activating fluid which may be the cement itself or any other predefined fluid for such a function and a desired reactivity. Figures 4A, B and C illustrate what happens to elements capable of swelling after they have been exposed to an activating fluid. In FIG. 4A, an activating fluid 56 has just begun to activate the swellable elements 58, 62. The fluid 56 continues to flow 60 into the casing. At this point, the duration = to, the thickness of the element capable of inflating = S0, and the pressure = P0, the pressure being measured between the discharge port of the pump and the inlet of the valve at the bottom casing. As shown in FIG. 4B, the activating fluid 56 continues to cause the inflatable members 64, 68 to inflate, and to slowly or immediately block the flow 66 of the activating fluid into the casing. At this point, the duration = tif the thickness of the element capable of inflating = Si, and the pressure = Pi. Figure 4C shows the state of the valve after the elements capable of inflating 70, 72 have fully inflated. . No more activating fluid 56 is allowed to flow into the casing. At this point, the duration = tf, the thickness of the element able to inflate = Sf, and the pressure = Pf.
    As illustrated in FIGS. 5A and 5B, as the thickness of the swellable element S increases, the surface pressure P increases, the results illustrating that Pf> P1> P0. When the surface pressure has increased to Pf, the pump on the surface can be stopped. This can be done either by an automatic stop command depending on a predetermined maximum pressure, or by an intervention of an operator.
    Referring to FIG. 6A, the valve system 100 is placed inside the wellbore 102, the valve 104 being placed inside the casing 106. The valve 104 is shown in the open position and the elements capable of inflating 108, 110 in contact with a non-activating fluid 112. In some embodiments, the non-activating fluid 112 is a drilling fluid, and flows through the valve 104 into the casing 106. A cement composition 114 is pumped through the annular space 116 to the bottom of the casing 106 and into the valve 104. As illustrated in FIG. 6B, when the cement composition 114 comes into contact with the elements capable of inflating the valve 108, 110 104, the inflatable members 114, 116 inflate, and close the valve 104. The cement composition 114 is prevented from entering the portion of the casing 106 located above the valve 104.
    In another embodiment, an activating fluid, separate from the cementitious composition, is used to trigger the elements capable of inflating the valve. As illustrated in FIG. 7A, the valve system 200 is placed inside the wellbore 202, the valve 204 being placed inside the casing 206. The valve 204 is shown in the open position and the elements capable of to inflate 208, 210 in contact with a non-activating fluid 212. In some embodiments, the non-activating fluid 212 is a drilling fluid, and flows through the valve 204 into the casing 206. An activating fluid 218 is pumped through the annular space 216 to the bottom of the casing 206 and into the valve 204. Following the activating fluid 218 comes the cement composition 214, which is pumped through the annular space 216 to the bottom of the casing 206 As illustrated in FIG. 7B, as the activating fluid 218 contacts the swellable elements 208, 210 of the valve 204, the swellable elements 214, 216 inflate, and close the valve 204. The cement composition 214 is emp to enter the part of the casing 206 situated above the valve 204.
    Fig. 8 is a flowchart detailing a procedure for performing a reverse circulation cementing operation. In reverse circulation cementing operation 300, the cement slurry is mixed 302 and additional additives or tracers capable of triggering the swelling elements can be added to 304. Thereafter, the cement is pumped down into the Annular space 306 and a displacement fluid is pumped behind the cement slurry 308. The surface pressure may increase due to the triggering of the inflation of the downhole valve elements by the additives or cement 310. The pressure is monitored at the surface 312. If the surface pressure does not increase 314, the surface pressure then continues to be monitored 312. If the surface pressure increases 314, then the reverse circulation cementing task then the pump is stopped 316 and the task is accomplished when drying the cement.
    A plurality of devices may be placed along the casing string with different expected expansion capabilities (maximum to minimum expansion valves placed from top to bottom) for the purpose of generating a plurality of signals (pressure peaks) at the same time. surface as a measure of redundancy or binary communication (in other words, pressure pulses) of the detection action.
    In another embodiment, the swellable fluid control device may be designed to also prevent backflow of annular fluids into the tubing, thereby avoiding the calculation and application of backpressure during the hydration of the cement to prevent any reflux.
    Flow control devices
    The methods and apparatus of the present disclosure include a flow control device. In some embodiments, this device is located in the casing near the bottom of a wellbore or at any other desired position. In one embodiment, the device is a valve, as illustrated in the foregoing sections. Any suitable construction valve may be used, for example, ball valves, sleeve valves, butterfly valves, check valves, throttle valves, diaphragm valves, pressure regulators, pressure, thermal expansion valves, electrorheological fluid valves, but this without limitation.
    Figures 9A-9C illustrate alternative flow control devices. A capsule-shaped device coated with a material capable of swelling is shown in Fig. 9A and cross-section 9B. The device 400 comprises a casing 402, a spider of the tower 404, and a swellable liner 406 surrounding a cap 408. In contact with an activating fluid, the swellable liner 406 inflates, thereby closing a flow path of fluid.
    Figure 9C illustrates the cross-section of a honeycomb-shaped device including a coating capable of swelling within it. A device 410 comprises a casing 412 and a hollow cell matrix 414 each containing a swellable coating 416 on the walls of each individual cell 414. In contact with an activating fluid, the swellable liner 416 swells and closes completely. or partially cells to the flow of a fluid. triggers
    The methods and apparatuses of the present disclosure may be activated by a triggering event. The trigger can be chemical, physical, or both. Chemical triggers include pH change, oxidation and reduction, solvent exchange, ionic strength change, oil-based change. Some materials are sensitive to changes in pH such as, for example, an alkalinity sensitive latex material. This material swells when it is exposed to fluids of high pH, cement for example. A drilling mud with a pH of about 7 could be displaced with a cement with a pH of about 11 to 13, causing the material to swell. The material may also shrink when exposed to low pH such as, for example, an acid pill for reversible effects.
    Physical triggers may include light irradiation, temperature change, physical deformation, magnetic field application, electric field application, microwave irradiation, temperature, pressure gradients, and combinations thereof.
    Materials capable of inflating
    The methods and apparatus of the present disclosure include materials capable of swelling. The material can be any material that swells when exposed to one of the triggers mentioned above. In general, the dimensions of the swellable materials applied to a regulating device are such that, when this material swells completely, the flow area of the flow control device is hermetically sealed completely or partially according to the design requirements.
    A useful swelling material is a pH sensitive polymer such as that described by Dai et al. in Soft Matter, 2008, 4, 435-449. The solubility, volume, configuration and conformation of a pH-sensitive polymer can be reversibly manipulated by changing the external pH. Most pH-sensitive polymers and microgels are synthesized by batch emulsion polymerization using water-soluble initiators. In addition, pH-sensitive polymers can be produced using controlled polymerization techniques such as, for example, anionic polymerization and group transfer polymerization.
    Another useful swelling material is an alkalinity sensitive latex material, which may be defined as a latex emulsion which, when exposed to pH increasing materials, may swell and exhibit an increase in its viscosity. . Alkali-sensitive latex materials capable of swelling generally contain, in addition to typical latex formation monomers, monomers having acidic groups capable of reacting with pH-increasing materials, and thereby forming anionic pendant groups on the polymer backbone. Due to the presence of acidic groups, alkali-sensitive latex emulsions capable of swelling have a pH in the range of about 2 to about 8 and are primarily low viscosity fluids with viscosities of less than About 100 centipoise for an emulsion containing 30% solids. When the pH is increased by the addition of a pH increasing material, the increase in viscosity may range from about five times to more than about one million times for a 30% emulsion. The viscosity of the conventional latex emulsion does not increase significantly when a pH increasing material is added. In some embodiments, the latex emulsion may be crosslinked during the polymerization phase of the monomers. Examples of typical latex forming monomers that can be used to produce swellable alkalinity sensitive latex materials include, but are not limited to, vinyte-aromatic monomers (eg, styrene-based monomers) ethylene, butadiene, vinyl nitrile (eg acrylonitrile), olefinically unsaturated esters of a C 1 -C 8 alcohol, or combinations thereof. In some embodiments, nonionic monomers that exhibit steric effects and that contain long hydrocarbon or ethoxylated tails may also be present. Monomers containing acidic groups capable of reacting with pH increasing materials include ethylenically unsaturated monomers containing at least one carboxylic acid functional group. Such carboxylic acid-containing monomers may be present in the range of from about 5% to about 30% by weight of the total monomer composition used in the preparation of the swellable alkalinity sensitive latex material. Non-limiting examples of such carboxylic acid-containing groups include acrylic acid, alkylacrylic acids such as methacrylic acid and ethacrylic acid, alpha-chloroacrylic acid, alpha-cyanoacrylic acid, alpha-chloro-methacrylic acid, alpha-cyano-methacrylic acid, crotonic acid, alpha-phenyl acrylic acid, beta-acryloxypropionic acid , sorbic acid, alpha-chioro-sorbic acid, angelic acid, cinnamic acid, p-chloro cinnamic acid, beta-styryl acrylic acid (1-carboxy- 4-phenylbutadiene-1,3), itaconic acid, maleic acid, citraconic acid, mesaconic acid, glutaconic acid, aconitic acid, acid fumaric, ethylene tricarboxy, or combinations of these elements. In one embodiment, the carboxylic acid-containing groups may include itaconic acid, acrylic acid, or combinations thereof.
    Various materials capable of swelling are known to those skilled in the art, these swelling materials when they are brought into contact with water and / or a hydrocarbon fluid, so that an exhaustive list of these materials will not be presented. in this document. Partial lists of swellable materials can be found in U.S. Patent Nos. 3,385,367 and 7,059,415, and in U.S. Published Application No. 2004/0020662.
    The water-swellable polymeric material may be a rubber mix comprising natural rubber (NR) or synthetic rubber such as, for example, cis-1,4-polyisoprene (IR) synthetic rubber, polybutadiene rubber (BR) , a randomly copolymerized rubber of styrene and a diene monomer (SBR or SIR), a copolymer rubber of acrylonitrile and a diene monomer (NBR or NIR), a chloroprene rubber (CR), a copolymer rubber of isobutylene and isoprene (IIR), a ternary copolymer rubber of ethylene, propylene and a diene monomer (EPDM), a poly (trans-1,4-isoprene) rubber, a block copolymerized rubber of styrene and a monomer diene, and the like, a water-absorbent resin, a vulcanizing agent, a vulcanization accelerator, a filler, an aging retarder, and the like.
    Alternatively, the water-swellable polymeric material may be a blend of a synthetic resin having some flexibility such as, for example, chlorinated polyethylenes, copolymers of ethylene and vinyl acetate, plasticized polychloride resins vinyl, polyurethanes, and the like, with a high water-absorbing resin and other additives. Other materials include swellable sol-gels such as those described in U.S. Patent No. 8,119,759, which are activated when exposed to a non-polar sorbate.
    Cement porridge
    A variety of cements may be used in the present invention, such as, for example, cements comprising calcium, aluminum, silicon, oxygen, and / or sulfur, which set and cure by reaction with some water ; or those such as resin-based systems that also have at least two components that react and harden over time. Such hydraulic cements include Portland cements, hard plasters, high aluminum cements, slag cements, high magnesium cements, shale cements, acid / base cements, ashes containing cements flywheels, cement-zeolite systems, cement kiln dust systems, microfine cements, metakaolin, pumice, and their combinations, as well as resin-based systems. In some embodiments, suitable Portland API cements are those of Classes A, C, H and G.
    The cement compositions of the invention may contain additives. In some embodiments, the additives comprise at least one of resins, latex, stabilizers, silica, pozzolans, microspheres, aqueous superabsorbents, viscosifiers, suspending agents, dispersing agents, salt, accelerants, surfactants, slowing agents, defoamers , sedimentation prevention agents, weighting materials, fluid loss control agents, elastomers, vitrified shale, gas migration control additives, formation conditioning agents, and combinations thereof.
    In some embodiments, the cement compositions have a slurry density for pumping and downhole introduction. In exemplary embodiments, the density of the slurry cement composition is from about 7 pounds per gallon (ppg) to about 20 ppg (ie, from about 840 kg / m 3 to about 2400 kg / m 2). m3 approximately), from about 8 ppg to about 18 ppg (or about 960 kg / m3 to about 2200 kg / m3), or from about 9 ppg to about 17 ppg (or about 1100 kg / m3 to about 2000 kg) / m3 approximately).
    Displacement fluid
    The displacement fluid may comprise a water-based fluid. In some embodiments, the water-based fluid comprises at least one of fresh water; brackish water; salt water; and combinations of these elements. The water can be fresh water, brackish water, salt water, or any combination of these elements. The displacement fluid can also be a petroleum-based fluid.
    Activating fluid
    The activating fluid is any fluid that causes the swelling of materials capable of swelling. This fluid may contain water and / or hydrocarbon fluids (such as oil or gas, for example). The activating fluid must be sufficiently viscous to be able to maintain a substantial separation between a first fluid, such as a drilling fluid for example, and a cementitious composition. In one embodiment, the activating fluid is a water-based fluid or a petroleum-based fluid. Those skilled in the art will be familiar with how to modify fluids or "pills" to maintain separation between two different treatment fluids. The activating fluid may contain particles that cause the swellable materials to swell. In one embodiment, the activating fluid may be the cement system itself.
    Drilling Wells and Formation In general terms, an area refers to an interval of rock along a wellbore, which is distinguished from surrounding rocks by its hydrocarbon content or other characteristics such as, for example, perforations or other type of fluid communication with the wellbore, defects or fractures. As used herein, the term "in a well" means introduced at least into and through the wellhead. According to various methods known in the art, equipment, tools or well fluids can be directed from the wellhead into any desired portion of the wellbore. In addition, a well fluid can be directed from a portion of the wellbore into the rock matrix of a zone.
    Although preferred embodiments of the invention have been shown and described, modifications thereof may be made by those skilled in the art without departing from the spirit of the teachings of the invention. The embodiments described herein are provided by way of example only and are not intended to be limiting. Many of the variations and modifications of the invention described herein are possible and are within the scope of the invention. The use of the term "optional" in relation to any element of a claim is intended to indicate that the object element is required or, alternatively, that it is not required. Both alternatives are intended to fall within the scope of the claim.
    Embodiments disclosed herein include: A: A method of detecting the presence of a downhole fluid at a particular position in a wellbore, pumping an activating fluid into a wellbore comprising a column casing string contacting a flow control device in the column casing string with the activating fluid, the flow control device being placed in the column casing string, and the device flow control device comprising at least one swellable member, wherein upon activation, the at least one swellable member inflates and seals, partially or completely, the flow region of the flow control device thereby regulating at least one of a flow rate, a pressure, and a combination thereof; activating the at least one element capable of inflating in the flow control device, thereby creating an activated flow control device; blocking fluids or regulating the flow of fluids entering or exiting the casing with the activated flow control device; allowing a change of pressure; and detecting the change in pressure. B: A method of cementing into a wellbore, comprising pumping an activating fluid through an annulus between a drill string and the wellbore or through the columnar tubing string; pumping at least one of a cement slurry, a resin-based fluid, and combinations thereof, through an annulus between a drill string and the wellbore or through the column casing string; contacting a flow control device in the column casing string with the activating fluid, the flow control device comprising at least one element capable of inflating, wherein upon activation, the at least one swellable member swells and tightly seals, partially or completely, the flow area of the flow control device, thereby controlling at least one of a flow rate, a pressure, and a combination of these elements; activating the at least one element capable of inflating in the flow control device, thereby creating an activated flow control device; and blocking or regulating the activating fluid with the activated flow control device. C: An apparatus for blocking or regulating fluid flow in a wellbore, the apparatus comprising: a drill string in a wellbore; and a flow control device in the column casing string, wherein the flow control device comprises at least one element capable of inflating, wherein during an activation trigger, the at least one element capable of swelling inflates and seals, partially or completely, the flow region of the flow control device, thereby blocking or regulating the flow of fluids into or out of the drill string. D: A system for generating a pressure peak or pressure pulses when a downhole fluid is present at a particular position in a wellbore, the system comprising: an apparatus comprising a drill string in a wellbore; drilling; and a flow control device in the column casing string near the bottom of the wellbore, wherein the valve comprises at least one element capable of inflating, wherein upon activation triggering, the at least one swellable member swells and tightly seals, partially or completely, the flow region of the flow control device, thereby blocking or regulating the flow of fluids into or out of the drill string; pumping an activating fluid into the wellbore; pumping a downhole fluid into the wellbore; contacting the flow control device in the column casing string with the activating fluid; activate the at least one element capable of inflating in the flow control device, thereby creating an activated flow control device; blocking or regulating the flow of downhole fluids or activating fluids entering or exiting the casing with the activated flow control device; and allow a peak or pressure pulse. A method for generating a pressure peak or pressure pulses when a downhole fluid is present at a particular position in a wellbore, the method comprising: providing and / or using a apparatus comprising a drill string in a wellbore, and a flow control device in the columnar tubing string near the bottom of the wellbore, wherein the valve comprises at least one element capable of inflating, wherein during an activation trigger, the at least one swellable element swells and tightly seals, partially or completely, the flow region of the flow control device, thereby blocking or regulating the flow of fluids in or outside the drill string, pumping an activating fluid into the wellbore, pumping a downhole fluid into the wellbore, contacting the flow control device in the column casing string with the activating fluid; activate the at least one element capable of inflating in the flow control device, thereby creating an activated flow control device; blocking or regulating the flow of downhole fluids or activating fluids entering or exiting the casing with the activated flow control device; and allow a peak or pressure pulse.
    Each of Embodiments A, B, C, D and E may comprise one or more of the following additional elements, in any combination: Element 1: wherein the flow control device is a valve. Element 2: wherein the at least one swellable element comprises at least one of pH sensitive materials, hydrogels, polyelectrolytes and combinations thereof. Element 3: wherein the activation comprises at least one trigger selected from pH change, oxidation and reduction, solvent exchange, ionic strength change, oil based change, light irradiation, change. temperature, physical deformation, magnetic field application, electric field application, microwave irradiation, temperature, pressure gradients, and combinations thereof. Element 4: wherein the detection comprises monitoring pressure increases of the surface pressure. Element 5: further comprising a plurality of flow control devices at different positions, resulting in a series of pressure pulses that are communicated to the surface as a result of a plurality of pressure events created by the plurality of swellings of the plurality of flow control devices. Element 6: wherein the flow control device is a mass-stem valve or shoe valve, or any other type of valve located at any desired position within the casing string. Element 7: wherein the inflation-swelling member of the valve comprises a material capable of swelling on at least one of the valve head, valve stem, and combinations thereof. Element 8: further comprising deactivating the swellable element. Element 9: wherein the deactivation comprises pumping a fluid into the wellbore which causes the contraction of the swellable element. Item 10: wherein the at least one of a cement slurry and a resin-based fluid and the activating fluid are pumped through the column casing string, and the at least one of a slurry of cement and a resin-based fluid is pumped before the activating fluid. Element 11 further comprising placing a cement plug in the casing between the pumping of the at least one of a cement slurry and of a resin-based fluid and the pumping of the activating fluid. Element 12: wherein the at least one of a cement slurry and a resin-based fluid and the activating fluid are pumped through the annulus between the drill string and the wellbore, and the activating fluid is pumped before the at least one of a cement slurry and a resin-based fluid. Element 13: wherein the activating fluid is also the at least one of a cement slurry and a resin-based fluid. Element 14: wherein the flow control device is a valve. Element 15: further comprising allowing a pressure change, and detecting the change in pressure. Element 16: wherein the detection comprises monitoring pressure increases of the surface pressure. Element 17: further comprising a plurality of flow control devices at different positions, resulting in a series of pressure pulses that are communicated to the surface as a result of a plurality of pressure events created by the plurality of swellings of the plurality of flow control devices. Element 18 further comprising adjusting the flow rate of the at least one of a cement slurry and a resin-based fluid when the surface pressure increases rapidly or a series of pressure pulses are generated. communicated to the surface. Element 19: further comprising at least one of stopping the flow of the at least one of a cement slurry and a resin-based fluid, adjusting the flow rate of the at least one one of a slurry of cement and a resin-based fluid, and their combination. Element 20 further comprising pumping a displacement fluid through the annulus behind the at least one of a cement slurry and a resin-based fluid before the at least one a slurry of cement and a resin-based fluid has come into contact with the flow control device. Element 21: wherein the at least one of a cement slurry and a resin-based fluid comprises at least one of an additive, a tracer, and combinations thereof, which activates the at least one element capable of inflating. Element 22: wherein the deactivation comprises pumping a fluid down the casing or annulus which causes contraction of the inflatable member. Element 23: further comprising detecting the tip or pressure pulse on the surface of the wellbore. Element 24: In which the detection of the tip or pressure pulse indicates that a downhole fluid is present near a certain downhole position. Element 25: wherein the indication that the downhole fluid is present near a certain downhole position is performed without downhole wired communications.
    Many other modifications, equivalents and variations will readily become apparent to those skilled in the art once the full extent of the foregoing disclosure has been fully taken. It is intended that the following claims be interpreted so as to encompass all such modifications, equivalents and variants as appropriate.
    权利要求:
    Claims (30)
    [1" id="c-fr-0001]
    A method of detecting the presence of a downhole fluid at a particular position in a wellbore (18, 102, 202), characterized in that the method comprises: pumping an activating fluid (56). ) in a wellbore (18, 102, 202) comprising a column casing string (20); contacting a flow control device (40, 100, 200) in the column casing string (20) with the activating fluid (56), the flow control device (40, 100, 200, 400, 410) being placed in the column casing string (20), and the flow control device (40, 100, 200, 400, 410) comprising at least one inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216), wherein upon activation, the at least one element capable of inflating (48, 50, 58 , 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) partially or completely seals and seals the flow region of the flow control device (40, 100, 200, 400, 410), thereby regulating at least one of a flow rate, a pressure, and a combination thereof; activating at least one element capable of inflating (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) in the control device of flow rate (40, 100, 200, 400, 410), thereby creating an activated flow control device; blocking the fluids or regulating the flow of fluids entering or exiting the casing (106, 206) with the activated flow control device; allowing a change of pressure; and detecting the change in pressure.
    [2" id="c-fr-0002]
    A method of cementing into a wellbore (18, 102, 202), characterized in that the method comprises: pumping an activating fluid (56) through an annular space (26, 116, 216) between a drill string and the wellbore (18, 102, 202) or through the column casing string (20); pumping at least one of a cement slurry, a resin fluid, and combinations thereof, through an annulus (26, 116, 216) between a drill string and the wellbore (18, 102, 202) or through the columnar tubing string (20); contacting a flow control device (40, 100, 200, 400, 410) in the column casing string (20) with the activating fluid (56), the flow control device (40, 100, 200, 400, 410) comprising at least one element capable of swelling (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216), wherein upon activation, at least one inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) inflates and seals, partially or completely, the flow area of the flow control device (40, 100, 200, 400, 410), thereby regulating at least one of a flow rate, a pressure, and a combination of these elements; activating the at least one swellable element (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) in the flow control (40, 100, 200, 400, 410), thereby creating an activated flow control device; and blocking or regulating the activating fluid (56) with the activated flow control device.
    [3" id="c-fr-0003]
    The method of claim 2, wherein the at least one of a cement slurry and a resin fluid and the activating fluid (56) are pumped through the column casing string (20). and the at least one of a cement slurry and a resin fluid is pumped before the activating fluid (56).
    [4" id="c-fr-0004]
    The method of claim 3, further comprising placing a cement plug in the tubing (106, 206) between pumping the at least one of a cement slurry and a fluid-based fluid. resin and pumping of the activating fluid (56).
    [5" id="c-fr-0005]
    The method of claim 2, wherein the at least one of a cement slurry and a resin-based fluid and the activating fluid are pumped through the annular space (26, 116, 216) between the drill string and the wellbore (18, 102, 202), and the activating fluid (56) is pumped before the at least one of a cement slurry and a resin-based fluid.
    [6" id="c-fr-0006]
    The method of claim 5, further comprising pumping a displacement fluid through the annulus (26, 116, 216) behind the at least one of a cement slurry and a fluid to resin base before the at least one of a cement slurry and a resin-based fluid has come into contact with the flow control device (40, 100, 200, 400, 410).
    [7" id="c-fr-0007]
    The method of claim 5 or 6, wherein the activating fluid (56) is also at least one of a cement slurry and a resin-based fluid.
    [8" id="c-fr-0008]
    The method of claim 7, wherein at least one of a cement slurry and a resin-based fluid comprises at least one of an additive, a tracer, and combinations of these elements, which activates i'at least one element capable of swelling (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216).
    [9" id="c-fr-0009]
    The method of any one of claims 2 to 8, further comprising permitting a pressure change and detecting the pressure change.
    [10" id="c-fr-0010]
    The method of claim 1 or 9, wherein the detecting comprises monitoring increases in pressure of the surface pressure,
    [11" id="c-fr-0011]
    The method of claim 10, further comprising a plurality of flow control devices (40, 100, 200, 400, 410) at different positions, resulting in a series of pressure pulses that are communicated to the surface in resulting from a plurality of pressure events created by the plurality of inflations of the plurality of flow control devices (40, 100, 200, 400, 410).
    [12" id="c-fr-0012]
    The method of claims 9 and 11, further comprising adjusting the flow rate of the at least one of a cement slurry and a resin-based fluid when the surface pressure increases rapidly or when series of pressure pulses are imparted to the surface (16).
    [13" id="c-fr-0013]
    The method of claims 9 and 11, further comprising at least one of stopping the flow of the at least one of a cement slurry and a resin-based fluid, adjusting the flow rate of the at least one of a cement slurry and a resin-based fluid, and their combination.
    [14" id="c-fr-0014]
    The method of any one of claims 1 to 13, wherein the flow control device (40, 100, 200, 400, 410) is a mass-stem valve or a shoe valve (42), or any other type of valve placed at any desired position within the casing string.
    [15" id="c-fr-0015]
    The process according to claim 14, wherein the swellable element (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) of the valve comprises a material capable of swelling on at least one of the valve head, the tail of the valve, and combinations thereof.
    [16" id="c-fr-0016]
    The method of any one of claims 1 to 15, further comprising deactivating the inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116 , 208, 210, 214, 216).
    [17" id="c-fr-0017]
    The method according to claims 1 and 16, wherein the deactivation comprises pumping a fluid into the wellbore (18, 102, 202) which causes contraction of the inflation-capable element (48, 50, 58). , 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216).
    [18" id="c-fr-0018]
    The method of claims 2 and 16, wherein the deactivation comprises pumping a fluid down the casing (106, 206) or the annulus (26, 116, 216) which causes the contraction of the swellable element (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216).
    [19" id="c-fr-0019]
    The method of any one of claims 1 to 18, wherein the flow control device (40, 100, 200, 400, 410) is a valve.
    [20" id="c-fr-0020]
    20. A method according to any one of claims 1 to 19, wherein Tau at least one element capable of swelling (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) comprises at least one of pH sensitive materials, hydrogels, polyelectrolytes and combinations thereof.
    [21" id="c-fr-0021]
    The method of any one of claims 1 to 20, wherein the activation comprises at least one trigger selected from pH change, oxidation and reduction, solvent exchange, ionic strength change, change. based on petroleum, light irradiation, temperature change, physical deformation, magnetic field application, electric field application, microwave irradiation, temperature, pressure gradients, and combinations thereof.
    [22" id="c-fr-0022]
    An apparatus for blocking or regulating fluid flow in a wellbore (18, 102, 202), characterized in that the apparatus comprises: a drill string in a wellbore (18, 102, 202); and a flow control device (40, 100, 200, 400, 410) in the column casing string (20), wherein the valve comprises at least one inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216), wherein during an activation trigger, the at least one inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) partially or completely seals and seals the flow region of the flow control device (40). , 100, 200, 400, 410) thereby blocking or regulating the flow of fluids into or out of the drill string.
    [23" id="c-fr-0023]
    Apparatus according to claim 22, wherein the at least one inflatable member (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) comprises at least one of pH-sensitive materials, hydrogels, polyelectrolytes and combinations thereof.
    [24" id="c-fr-0024]
    The apparatus of claim 22 or 23, wherein the activation trigger comprises at least one trigger selected from a pH change, an oxidation and a reduction, a solvent exchange, a change in ionic strength, a change based on petroleum, light irradiation, temperature change, physical deformation, magnetic field application, electric field application, microwave irradiation, temperature, pressure gradients, and combinations thereof.
    [25" id="c-fr-0025]
    Apparatus according to any one of claims 22 to 24, wherein the flow control device (40, 100, 200, 400, 410) is a valve.
    [26" id="c-fr-0026]
    Apparatus according to claim 25, wherein the swellable element (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) of the valve comprises a material capable of swelling on at least one of the valve head, the tail of the valve, and combinations thereof.
    [27" id="c-fr-0027]
    A system for generating a pressure peak or pressure pulses when a downhole fluid is present at a particular position in a wellbore, characterized in that the system comprises: an apparatus comprising: a drill string in a wellbore (18, 102, 202); and a flow control device (40, 100, 200, 400, 410) in the column casing string (20) near the bottom of the wellbore, wherein the valve comprises at least one element capable of inflating ( 48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216), wherein during an activation trigger, the at least one element capable of swelling (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) swells and seals, partially or completely, the flow area the flow control device (40, 100, 200, 400, 410) thereby blocking or regulating the flow of fluids into or out of the drill string; pumping an activating fluid (56) into the wellbore (18, 102, 202); pumping a downhole fluid into the wellbore (18, 102, 202); contacting the flow control device (40, 100, 200, 400, 410) in the column casing string (20) with the activating fluid (56); activating the at least one inflatable element (48, 50, 58, 62, 64, 68, 70, 72, 108, 110, 114, 116, 208, 210, 214, 216) in the flow control device (40, 100, 200, 400, 410), thereby creating an activated flow control device; blocking or regulating the flow of downhole fluids or activating fluids (56) entering or exiting the casing (106, 206) with the activated flow control device; and allow a peak or pressure pulse.
    [28" id="c-fr-0028]
    The system of claim 27, further comprising detecting the tip or pressure pulse on the surface (16) of the wellbore (18, 102, 202).
    [29" id="c-fr-0029]
    The system of claim 28, wherein detecting the tip or pressure pulse indicates that a downhole fluid is present near a certain downhole position.
    [30" id="c-fr-0030]
    The system of claim 29, wherein the indication that the downhole fluid is present near a certain downhole position is performed without downhole wired communications.
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    同族专利:
    公开号 | 公开日
    GB201802674D0|2018-04-04|
    CA2994102A1|2017-03-30|
    NO20180026A1|2018-01-08|
    US10753176B2|2020-08-25|
    GB2556007B|2021-05-12|
    US20180245427A1|2018-08-30|
    AU2015410225A1|2018-02-01|
    GB2556007A|2018-05-16|
    AU2015410225B2|2021-03-11|
    WO2017052629A1|2017-03-30|
    MX2018002089A|2018-06-18|
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    法律状态:
    2017-07-26| PLFP| Fee payment|Year of fee payment: 2 |
    2018-07-18| PLFP| Fee payment|Year of fee payment: 3 |
    2019-08-30| PLFP| Fee payment|Year of fee payment: 4 |
    2020-03-13| PLSC| Search report ready|Effective date: 20200313 |
    2021-04-30| RX| Complete rejection|Effective date: 20210325 |
    优先权:
    申请号 | 申请日 | 专利标题
    PCT/US2015/052381|WO2017052629A1|2015-09-25|2015-09-25|Swellable technology for downhole fluids detection|
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