Classifications

• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B47/00—Survey of boreholes or wells
  • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B33/00—Sealing or packing boreholes or wells
  • E21B33/10—Sealing or packing boreholes or wells in the borehole
  • E21B33/12—Packers; Plugs
  • E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells

Definitions

• the present invention relates to monitoring subterranean formations and more particularly, systems and methods for monitoring a parameter of a subterranean formation using swellable materials.
• Challenges with downhole measurements may include securely coupling sensor packages to the rock mass, isolating the packages as much as possible from noise in the wellbore, and providing cabling paths (if necessary) for transmitting data to the surface.
• Sensors may be deployed permanently or retrievably.
• Retrievable sensors packages are often deployed on wirelines, but also on coiled tubing or production tubing.
• Wireline deployed arrays may use clamp arms, magnets, or bow springs for coupling to the wellbore, whereas coiled tubing or tubing deployed arrays may have decentralizers and may be locked into the wellbore through friction and bending stresses.
• these types of deployment may be susceptible to coupling problems if the clamp arms do not fully extend, if magnets are placed over scale or other wellbore irregularities, or if the coiled tubing is not wedged against the casing wall.
• Permanent sensors may be cemented in place, but this can be a difficult and costly process for sizable sensor arrays.
• Successful deployments of large sensor arrays may have inserted the sensors coupled to tubing inside cemented casing with the tubing then cemented inside the casing. Attempts to directly place sensor arrays on the outside of casing have often been unsuccessful due to damage to the array during emplacement.
• a successful deployment of cemented sensors may remain susceptible to noise transferred either up or down the tubulars because of the affixation to the tubing or casing.
• Figures 1A and IB are partial schematic cross-sectional views of a monitoring system using swellable materials in accordance with an exemplary embodiment of the present invention.
• Figure 2 is schematic perspective view of a monitoring system using swellable materials in accordance with an exemplary embodiment of the present invention.
• Figure 3 is schematic perspective view of a monitoring system using swellable materials in accordance with an exemplary embodiment of the present invention.
• Figures 4A, 4B, 4C and 4D are schematic cross-sectional views of a monitoring system using swellable materials in accordance with an exemplary embodiment of the present invention.
• Figures 5A, 5B, 5C, 5D, 5E, 5F, 5G, 5H, 51 and 5J are schematic partial cross- sectional views of a monitoring system using swellable materials in accordance with an exemplary embodiment of the present invention.
• the present invention relates monitoring subterranean formations and more particularly, systems and methods for monitoring a parameter of a subterranean formation using swellable materials.
• a system for monitoring a parameter of a subterranean formation using swellable materials may include a sensor device configured to detect a parameter of a subterranean formation.
• the system may also include a swellable material configured to position the sensor device toward a surface of the subterranean formation by swelling of the swellable material.
• the system may further include a telescoping section coupled to the sensor device and emplaced in the swellable material. The telescoping section may be configured to extend with the positioning of the sensor device.
• the sensor device is emplaced at least partially in the swellable material.
• the swellable material is further configured to position the sensor device against the surface of the subterranean formation by swelling.
• the senor device is operative to communicate a signal related to the parameter of the subterranean formation.
• the telescoping section is configured to allow the positioning of the sensor device while the sensor device is operative to communicate a signal related to the parameter of the subterranean formation.
• the swellable material is on an exterior surface of a tubular body and is configured to position the sensor device away from the pipe by swelling.
• the swellable material is further configured to reduce an effect on the sensor device of acoustic noise traveling along the tubular body.
• a system for monitoring a parameter of a subterranean formation using swellable materials may include a sensing tool configured to detect a parameter of a subterranean formation.
• the sensing tool may include a generally tubular body.
• the system may also include a swellable material on an exterior surface of the generally tubular body.
• the swellable material may be configured to anchor the sensing tool in a position corresponding to a surface of the subterranean formation by swelling of the swellable material.
• the swellable material is further configured to substantially center the sensing tool between at least two opposing points on the surface of the subterranean formation.
• the swellable material comprises a plurality of swellable members disposed along the generally tubular body.
• the swellable material at least substantially surrounds a length the generally tubular body.
• the swellable material is configured to anchor the sensing tool against the surface of the subterranean formation.
• the swellable material comprises a plurality of swellable members disposed along the generally tubular body, wherein each swellable member partially surrounds a corresponding length of the generally tubular body.
• the swellable material longitudinally extends along a length of the generally tubular body.
• a method for monitoring a parameter of a subterranean formation may include introducing a sensing tool to a wellbore.
• the sensing tool may include a generally tubular body and is configured to detect a parameter of a subterranean formation.
• the method may also include positioning the sensing tool in a position corresponding to a surface of the wellbore by swelling a swellable material.
• the swellable material may be disposed on an exterior surface of the generally tubular body.
• the method may also include detecting a parameter of a subterranean formation with the sensing device.
• the positioning step comprises substantially centering the sensing tool between at least two opposing points on the surface of the wellbore.
• the swellable material comprises a plurality of swellable members disposed along the generally tubular body.
• the swellable material at least substantially surrounds a length the generally tubular body.
• the positioning step comprises anchoring the sensing tool against the surface of the wellbore.
• the swellable material longitudinally extends along a length of the generally tubular body.
• the sensing tool may be a part of the system described above.
• Certain embodiments of the present disclosed provide for a retractable sensor device and/or tool that may reenter a retracted state. Certain embodiments provide for swell controls that may be adapted for swelling and/or de-swelling swellable materials.
• the present invention relates monitoring subterranean formations and more particularly, systems and methods for monitoring a parameter of a subterranean formation using swellable materials.
• the systems, apparatuses and methods of the present disclosure may allow for the deployment of sensors in permanent, semi-permanent, and/or retrievable applications with minimal effect on the wellbore, superior coupling to the rock mass, minimal vibrational degrees of freedom, and significant isolation from the wellbore noise for those cases where monitoring of the reservoir is desirable.
• sensors may be at least partially emplaced within swell packers for direct coupling to tubulars with maximum isolation from the rock mass for cases where it is desirable to monitor the tubing deformation and/or flow noise/activity within the tubing.
• Such swell packers may be constructed of elastomers that swell when exposed to either hydrocarbons or water, depending upon the application, in order to seal off and isolate zones within the wellbore.
• the swell packers may provide coupling by swelling and forcing a sensor package against either a formation, a wellbore, or any rigid contact point.
• swellable materials may be implemented to centralize or decentralize sensors and/or sensor tools within a wellbore, depending on the desirability of placing the sensors and/or sensor tools in a central or decentralized position.
• Embodiments of the present disclosure may be applicable to horizontal, vertical, deviated, or otherwise nonlinear wellbores in any type of subterranean formation. Embodiments may be applicable to injection wells as well as production wells, including hydrocarbon wells. In addition well bore and well casing implementations, embodiments may be applicable for securely planting surface instruments in soft, crumbly ground.
• Figure 1A illustrates a system 100 where a tubular body 105 having an axis 105A is shown disposed in a wellbore 140 and adjacent to the wall 120.
• the tubular body 105 may be disposed in an uncased section of wellbore 140, but the tubular body 105 may be disposed in a cased section or in near-surface ground in other embodiments.
• the tubular body 105 may provide a conduit for formation fluids to travel therethrough.
• the system 100 may include a sensor package 110 fully or partially encased in a swellable element 1 15.
• the sensor package 110 may be disposed at or near an outer boundary of the swellable element 1 15.
• the sensor package 1 10 may include, for example, a sonde, a geophone, an accelerometer, a hydrophone, or another device that detects ground motion due to either source shots (e.g., vertical seismic profiling or crosswell surveys) or passive behavior such as microseismicity and/or noise in both the wellbore and the reservoir.
• the sensor package 1 10 may include a sensor for measuring deformation in the downhole environment, such as a tiltmeter that measures the gradient of displacement, or any instrument that measures differential displacement in the reservoir.
• a line 135 may be coupled to the sensor package 110.
• the line 135 may be any one, or a combination, of a multi-conductor cable, a single conductor cable, a fiber optic cable, a fiber optic bundle, and a conduit or umbilical that contains cables, fiber optics and control lines to provide a hydraulic connection down hole.
• the line 135 may be a wireline.
• the line 135 may be a means of placing the sensor package 110 in the wellbore 140.
• the sensor package 110 and the swellable material may be coupled to the tubular body 105 and introduced into the wellbore 140 together.
• the line 135 may also be a means of communicating electrical signals, such as indications of a parameter associated with the subterranean formation, between the sensor package 1 10 and a data collection system and/or control system at remote location, such as the earth's surface or a subsea location.
• the line 135 may be a means of communicating with another well tool at another location in the wellbore 140 or another wellbore. As depicted, a portion of the line 135 may be encased in the swellable element 1 15.
• the sensor package 1 10 may communicate via any type of telemetry, such as acoustic, pressure pulse, electromagnetic telemetry or any wireless means.
• FIG. IB therein is depicted the system 100 of Figure 1A with the swellable element 1 15 in an expanded configuration.
• the swellable element 1 15 comes in contact with an activating agent, the swellable element 1 15 expands radially outwardly.
• the swellable element 115 may come in contact with the wellbore wall 120 due to swelling.
• the sensor package 110 may include a telescoping section 130 configured to extend outwardly toward the wall 120 along with the expansion of the swellable element 115 such that the swellable element 115 in effect pulls the sensor package 110 toward the wall 120.
• the swellable element 1 15 may force the sensor package 1 10 to come into contact with the wall 120 and/or to partially or completely protrude into the wall 120.
• the telescoping section 130 may include any means by which the sensor package 1 10 may be displaced while maintaining connection with the portion of the line 135 encased in the swellable element 115.
• the telescoping member 130 may include an extensible arm or an expandable cavity within the swellable element 1 15 that houses a length of the line 135 with sufficient slack corresponding to the displacement of the sensor package 1 10.
• Certain embodiments may employ a single swellable element 1 15 as depicted in Figures 1 A and IB.
• Other embodiments may employ multiple swellable elements. Though not shown in Figures 1A and IB, one or more additional swellable elements may be placed about the tubing 105.
• the swellable element 115 may be made of different materials, shapes, and sizes.
• the swellable element 1 15 may be deployed on tubing with a symmetrical ring configuration.
• the swellable element 1 15 may take an annular form surrounding or partially surrounding the tubing 105, and may be any elastomeric sleeve, ring, or band suitable for expanding within a space between tubing 105 and an outer tubing, casing, or wellbore.
• the term "swell” and similar terms are used herein to indicate an increase in volume of a material. Typically, this increase in volume is due to incorporation of molecular components of a fluid into the swellable material itself, but other swelling mechanisms or techniques may be used, if desired.
• the swellable element 1 15 may include one or more swellable materials that swell when contacted by an activating agent, such as an inorganic or organic fluid.
• a swellable material may be a material that swells upon contact with and/or absorption of a hydrocarbon, such as oil.
• a swellable material may be a material that swells upon contact with and/or absorption of an aqueous fluid.
• the hydrocarbon is absorbed into the swellable material such that the volume of the swellable material increases creating a radial expansion of the swellable material when positioned around a base pipe which creates a radially outward directed force that may operate to radially extend telescoping members as described above.
• the swellable material may expand until its outer surface contacts the formation face in an open hole completion or the casing wall in a cased wellbore. The swellable material accordingly may provide the force to extend the telescoping member 130 of the sensor package 110 to the surface of the formation such as wellbore wall 120.
• Suitable swellable elements include, but are not limited, to the swellable packers disclosed in U.S. Patent Nos. 3,385,367; 7,059,415; and 7,143,832; the entire disclosures of which are incorporated by reference.
• the swellable element 1 15 may be individually designed for the conditions anticipated for a particular case, taking into account the expected temperatures and pressures for example.
• Some exemplary swellable materials may include elastic polymers, such as EPDM rubber, styrene butadiene, natural rubber, ethylene propylene monomer rubber, ethylene-propylene-copolymer rubber, ethylene propylene diene monomer rubber, ethylene-propylene-diene terpolymer rubber, ethylene vinyl acetate rubber, hydrogenized acrylonitrile butadiene rubber, acrylonitrile butadiene rubber, isoprene rubber, butyl rubber, halogenated butyl rubber, brominated butyl rubber, chlorinated butyl rubber, chlorinated polyethylene, chloroprene rubber and polynorbomene.
• elastic polymers such as EPDM rubber, styrene butadiene, natural rubber, ethylene propylene monomer rubber, ethylene-propylene-copolymer rubber, ethylene propylene diene monomer rubber, ethylene-propylene-diene terpolymer rubber, ethylene vinyl a
• these and other swellable materials may swell in contact with and by absorption of hydrocarbons so that the swellable material expands.
• the rubber of the swellable materials may also have other materials dissolved in or in mechanical mixture therewith, such as fibers of cellulose. Additional options may be rubber in mechanical mixture with polyvinyl chloride, methyl methacrylate, acrylonitrile, ethylacetate or other polymers that expand in contact with oil. Other swellable materials that behave in a similar fashion with respect to hydrocarbon fluids or aqueous fluids also may be suitable.
• the swellable materials may be permeable to certain fluids but prevent particulate movement therethrough due to the porosity within the swellable materials.
• the swellable material may have a pore size that is sufficiently small to prevent the passage of the sand therethrough but sufficiently large to allow hydrocarbon fluid production therethrough.
• the swellable material may have a pore size of less than 1 mm.
• the activating fluid/agent may comprise a hydrocarbon fluid or an aqueous fluid.
• an activating fluid may comprise additional additives such as weighting agents, acids, acid-generating compounds, and the like, or any other additive that does not adversely affect the activating fluid or swellable material with which it may come into contact.
• additional additives such as weighting agents, acids, acid-generating compounds, and the like, or any other additive that does not adversely affect the activating fluid or swellable material with which it may come into contact.
• it may be desirable to include an acid and/or an acid-generating compound to at least partially degrade any filter cake that may be present within a wellbore.
• the activation agent may be introduced to the swellable material in a variety of ways.
• the activation agent may be injected into the wellbore or casing from a source at the surface.
• the activation agent may be placed in the wellbore or casing and released on demand.
• swelling of the swellable material may be delayed, if desired.
• a membrane or coating may be on any or all surfaces of the material to thereby delay swelling of the material.
• the membrane or coating could have a slower rate of swelling, or a slower rate of diffusion of fluid through the membrane or coating, in order to delay swelling of the material.
• the membrane or coating could have reduced permeability or could break down in response to exposure to certain amounts of time and/or certain temperatures. Suitable techniques and arrangements for delaying swelling of a swellable material are described in U.S. Patent Nos. 7,143,832 and 7,562,704, the entire disclosures of which are incorporated herein by reference.
• the swellable materials of certain embodiments may be shrinkable or may be distintegratable.
• a deactivating fluid/agent for example, may comprise a salt compound that would cause the swelled materials to contract by way of osmosis.
• a disintegrating fluid agent for example, may comprise any chemical adapted to chemically destroy the swellable material. In either case, the shrinking or disintegrating of the swellable material allows for the unanchoring of the sensor device or tool.
• the system 100 may comprise a sampling package (not shown) in lieu of or in addition to the sensor package 110.
• the sampling package may comprise an extendable straw or functional equivalent.
• the swellable element 1 15 comes in contact with an activating agent, the swellable element 115 expands radially outwardly and may seal about an area of the wellbore wall 120.
• the sampling package, coming into contact with the formation may facilitate fluid flowing from the formation such that the fluid may be monitored by the sensors.
• the fluid from the formation at that spot may be used as a fluid power source.
• the sampling package, coming into contact with the formation may obtain a sample from the location. Then, by way of the de-swelling processes disclosed herein, the system 100 may be retracted from the wellbore 120 and the sample may be recovered from the sampling package.
• FIG. 2 illustrates a system 200 where a swellable element 215 provides for symmetric instrument tool clamping within a borehole or casing.
• a tool 205 may be or include a sensor device, a microseismic array tool, or any other tool for which vibrations degrade its fidelity.
• the tool 205 may comprise a tubular body and may be disposed in an uncased section of the wellbore 240. Alternatively, the tool 205 may be disposed in a cased wellbore.
• Certain embodiments may include umbilical lines, wirelines, or tubes to the surface that could be incorporated to provide for positioning and/or monitoring the tool 205 and downhole sensors, for electrically activated controls of subsurface equipment, for injecting chemicals, or any combination thereof.
• communication with the tool 205 may be achieved via any type of telemetry, such as acoustic, pressure pulse or electromagnetic telemetry.
• One or more swellable elements 215 may be coupled to the tool 205 and may be configured to expand to anchor symmetrically, or substantially symmetrically, the tool 205 against a wall 220 of the wellbore or casing.
• the swellable elements 215 may be configured to swell, due to contact with an activation agent, to a position 210. As illustrated by the position 210, the swellable elements 215 may come in contact with the wall 220 upon expansion.
• the swellable elements 215 may be any elastomeric sleeve, band, ring, or other annular form surrounding or partially surrounding the tubing 205 and suitable for expanding between the tool 205 and wall 220, as long as the swellable elements 215 anchor the tool 205 in a symmetrical or substantially symmetrical manner.
• the tool 205 may become well-centered in the wellbore or casing so that microseismic energy may reach the tool 205 substantially equally well from all sides.
• a symmetric, or substantially symmetric, system similar to system 200 may surround a geophone planted in a shallow surface borehole to suppress decoupled oscillations of the instrument.
• the areal contact of the swellable elements 215 with the tool 205 provides stiffening and allows shifting of modal vibrations to higher frequencies above the range of the microseisms or other sources that are being monitored. Because they expand into available space, the swelling elements themselves are very well suited for use in irregular boreholes as tool contact is necessarily hit-or-miss along the length of the tool in such settings. Similar swelling elements applied to surface-based acquisition sensors (e.g., shallow borehole geophones or tiltmeters) allow firm emplacement that, in contrast to permanent cementation, allows subsequent retrieval and reuse. In certain embodiments, the swellable elements 215 may form seals in the wellbore 240 by swelling.
• the swellable elements 215 accordingly may prevent fluid from flowing outside of an interval along the body of the tool 205.
• the swellable elements 215 may be configured to effectively isolate the entire, or nearly the entire, body of the tool 205, as desired.
• Figure 3 illustrates a system 300 where a swellable element 315 provides for asymmetric instrument tool clamping within a wellbore 340.
• One or more swellable elements 315 may be coupled to the tool 305 in an asymmetric manner so that the swellable elements 315 anchor the tool 305 in an asymmetrical manner.
• the tool 305 may be pushed up against a side 320 of the wellbore or casing, where the tool 305 may receive microseismic energy via direct contact.
• the swellable elements 315 may push the tool against the borehole wall more uniformly and firmly along its length, as compared to conventional approaches.
• tubing and/or wireline run with encased, ring, or partial ring deployment may have advantages that can be exploited for a given monitoring situation, as for example to shield against noise, temperature, or wellbore chemistry and to appropriately couple for what is actually being monitored.
• Figures 4A-4D illustrate a system 400 run on wireline using an eccentric swell packer for clamping a tool 405.
• a swellable element 415 may run along a length of the tool 405 to provide for asymmetric instrument tool clamping within a wellbore or casing.
• the swellable element 415 may fit along a holder 410.
• Figures 4 A and 4B depict the swellable element 415 prior to activation.
• Figures 4C and 4D depict the swellable element 415 in an expanded position after contact with an activation agent. The expansion may cause the swellable element 415 and the tool 405 to contact the wall 420 of the wellbore or casing.
• Figures 5A-5H illustrate a system 500 where a tubular body 505 is shown disposed in a wellbore or casing 540 and adjacent to the wall 575.
• Figures 5A and 5B respectively illustrate partial side and perspectives views of the system 500 in a retracted state.
• Figures 5C and 5D respectively illustrate partial side and perspectives views of the system 500 in an expanded state.
• the tubular body 505 may be encircled by an inner arrangement 510 and an outer arrangement 515.
• the tubular body 505 may be provided with ribbing 555 or other means configured to prevent rotation of the inner arrangement 510 about the tubular body 505.
• the tubular body 505 may be provided with one or more flanges 545 proximate to the inner arrangement 510 and configured to anchor the inner arrangement 510 so as to prevent axial movement with respect to the tubular body 505.
• the inner arrangement 510 and the outer arrangement 515 may respectively include components 51 OA and 515A, disposed in a generally circular, annular and/or cylindrical arrangement.
• components 51 OA, 515A generally form partial sectors or arcs.
• the components 51 OA, 515 A may be solid or hollow pieces and may be made of metal, composite or another type of suitable material.
• One or more sensor packages 550 may be coupled to the outer arrangement 515. Each sensor package 550 may have at least a portion extending into a component 515 A. In certain embodiments, one or more sensor packages may be coupled to the inner arrangement 505. In certain embodiments, one or more sensor packages may be coupled to both the inner arrangement 505 and the outer arrangement 515. In the latter embodiment, the sensor packages may be configured for noise-canceling in order to attenuate tubular-borne noise.
• the inner arrangement 510 and the outer arrangement 515 may be coupled by way of one or more struts 520.
• the struts 520 may be configured to have a degree of freedom and, for example, may be swivably attached to one or both of the inner arrangement 510 and the outer arrangement 515.
• a swivel attachment be associated with either one or the other of the inner arrangement 510 and the outer arrangement 515, so that both may maintain a stable configuration during insertion into or retrieval from the borehole.
• the swivel attachment may be of a hinge type and may have a vertical length around an axis of rotation.
• the swivel attachment may include paths for electrical signal lines.
• Adjacent components 51 OA, 515A may be coupled to each other.
• each component 51 OA, 515A may be coupled to an adjacent component 51 OA, 515A via a mandrel and or an expansion sleeve.
• adjacent components 51 OA of the inner arrangement 510 are coupled via expansion sleeves 525.
• Adjacent components 515A of the outer arrangement 515 are coupled via expansion sleeves 530.
• the expansion sleeves 525 and 530 may partially encase, surround or otherwise wrap around portions of adjacent circular components 51 OA and 515A, thereby aiding the generally circular alignment of the components 1 OA and 515A.
• the expansion sleeves 525 and 530 may be made of metal, composite or another type of suitable material.
• Figures 5E-5J illustrate one example of an expansion sleeve 530 about adjacent circular components 515A.
• Figure 5E illustrates an unexpanded state
• Figure 5F illustrates an expanded state.
• the adjacent components 51 OA may be configured to allow a region 535 between them when not flush.
• Swellable elements may be disposed in the region 535.
• elastomer 530A may be disposed in the region 535 with swell controls
• an expansion sleeve 525 and adjacent circular components 1 OA may be similarly configured.
• the swellable elements may be configured to expand generally tangentially to the inner arrangement 510 so that the inner arrangement 510 expands generally tangentially, as opposed to radially.
• the swellable elements in conjunction with other elements of system 500, provide a mechanism for the system 500 to detach from the tubular
• the swell controls 560 may include fluid and/or electrical lines 565 that may be configured to convey activation agent and/or activate valves 570.
• the valve 570 may include one or more reservoirs and may be operable to disperse the activation agent to the swellable materials 515A.
• 20 560 may be adapted for swelling the swellable materials 515A so that the system 500 may detach from the tubular body.
• the swellable elements may similarly provide a mechanism for reattachment.
• a deswelling agent may include salt to extract water from a water-swellable
• the electrical lines may later be used to expose the swellable elements to a deswelling agent in order to shrink the swellable material, thereby transitioning the tool to a retracted state that would allow for tool retrieval.
• the swell controls 560 may be adapted for de-swelling the swellable materials 515 A.
• Figures 5H and 51 show diagrams of one exemplary embodiment of a valve 570.
• the valve 570 may include a deswelling agent reservoir 572 and/or a swelling agent reservoir 574.
• a slide 576 may include ports that may be selectively aligned with a deswelling agent reservoir 572 and/or a swelling agent reservoir 574.
• Figure 51 depicts a view of the slide where ports 578A are shown in an open state and in aligned with a reservoir port. Ports 578B are shown in a closed state and not aligned with a reservoir port.
• the valve 570 may be configured with the slide 576 to allow for the controlled feed of an agent to the swellable material.
• the slide 576 may be activated by hydraulics or an electrical device such as an electromagnet on either end.
• valve 570 and the slide 576 may be adapted so the ports of the slide may be selectively aligned with the ports of a reservoir by rotation, rather than lateral motion of the slide 576 indicated in Figure 5H.
• the slide 576 may have a disk form with ports that may be rotated about a center.
• Figure 5J illustrates a mandrel 525A that may be used in the alternative or in addition to expansion sleeves to couple two or more adjacent circular components 51 OA and 515A.
• the mandrel 525A may be used as a one- or two-ended piston to prevent or minimize lateral expansion such that expansion is directed along an axis of the mandrel.
• secondary mandrels in the outer arrangement 515 may be preferred in order to shift the centerpoint of the inner arrangement 510 as the tubular body 505 may not always be well-centered in the borehole 540.
• a mandrel 525A may include an outer body 525B that at least partially surrounds an elastomer material 525C.
• the elastomer material 525C is shown in an at least partially expanded state.
• the outer body 525B may comprise metal, a composite, or any other suitable material.
• the system 500 allows sensor packages to be deployed in a state that has no direct physical contact or intermediate structural contact with the tubular body. Having the tool placed against the side of the borehole with no direct solid-to-solid contact with the tubular body, the sensor packages are afforded a degree of acoustic isolation from acoustics that may otherwise be transferred via the tubular body. Further, the system 500 provides a safety margin such that the tool may be spared from sharp, high-force, or uncontrolled movements that could endanger tubing, wiring, the borehole wall, or the tool.
• the generally circular outer arrangement 515 provides a perimeter that may allow for positioning while maintaining tolerance for irregularities that may be encountered in the surface of the borehole. Although system 500 is depicted with four circular components and four sensor packages in the outer arrangement 515, and four circular components in the inner arrangement 510, it should be understood that other embodiments may include a different number and combination of circular components and sensor packages.
• the inner arrangement 510 may be coupled to spring- powered extensions released to point inwards to the tubular body 505 in order to "measure" the radial distance between the inner arrangement 510 and the tubular body 505 at three or more points.
• the spring-powered extensions may restrict the flow of swelling agent into their respective components 51 OA, thereby allowing those swellable sections nearest the tubular to be expanded outwards more rapidly than those farther away, and thereby centering the inner arrangement 510 at a uniform distance from the tubular body 505.
• the extensions may be retracted into the inner arrangement 510.
• Certain embodiments of the present disclosure may provide a simpler, cheaper, and easier means of coupling sensors to a formation or tubing/casing that are likely to provide much surer coupling.
• Most previous sensor deployments have used cement coupling (generally for permanent deployments), mechanical coupling such as clamp arms and bow springs (for both permanent and retrievable applications), magnetic coupling (retrievable applications), or even uncoupled deployments (e.g., sensors attached to tubing run inside of casing) that rely on friction and bending stresses.
• Methods and systems of the present disclosure may eliminate the need for mechanical clamp arms (which may have leak issues with seals and high temperature), bow springs (which may have poor high frequency response and resonances), magnets (which may have limited coupling and resonances), or cementing.
• Methods and systems of the present disclosure may also improve omnidirectional array fidelity, even for retrievable operations and settings where the swelling elements may be subsequently de-swelled, detached or torn off to facilitate tool retrieval or repositioning.
• Certain embodiments of the present disclosure may allow for long-term emplacement in difficult open-hole environments without permanently cementing an instrument in place. This may simplify operations and may allow for retrievable sensor devices if difficulties occur during emplacement. This may avoid the situation in open-hole environments where mechanical arms or bowsprings can sink into soft materials in the hole and cause poor tool coupling. Such a situation can occur in shales and many shallow boreholes where sensors would otherwise have to be cemented in permanently to obtain good coupling.
• Certain embodiments may allow for improved signal fidelity for microseismic monitoring of hydraulic fractures by ensuring better coupling compared to clamp arms, bow spring, magnets, or other emplacement methods, thus attenuating or eliminating longitudinal tool vibrations that degrade the recording fidelity of elastic body wave motion parallel to a tool axis.
• swelling elements may effectively dampen acoustic noise generated by flow in production tubulars as well as noise received via the tubulars. The swelling elements may even yield sensor isolation from the tubulars even though swellable elements are in contact with both. Additionally, certain embodiments may allow for securely planting surface instruments in soft, crumbly ground.
• Certain embodiments may remove directional bias of recorded signals by emplacing sensors in the center of a borehole with equal response from all directions, as opposed to a likely higher fidelity on the side of the borehole on which it is deployed when clamped or cemented. Certain embodiments may eliminate the need for a nearby vertical observation well by allowing for installation of tools in the injection/production well with good coupling and a degree of noise suppression from tubing activities.
• Certain embodiments may be used for time-lapse seismic monitoring and/or time- lapse deformation monitoring throughout the life of the reservoir for more permanent installations.
• the time-lapse seismic application requires a source on either the surface or in a nearby well; time-lapse deformation only requires continuous measurements of tilt or other deformation parameters.
• certain embodiments provide a fast, easy method to deploy sensors, potentially allowing them to stabilize much faster—which translates to a shorter lead time for monitoring.

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• 2010
  • 2010-09-02 US US12/874,917 patent/US20120055669A1/en not_active Abandoned
• 2011
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