Abstract: A method can include conveying a dispensing tool through a wellbore, the dispensing tool including an enclosure containing plugging devices, and then opening the enclosure by cutting a material of the enclosure, thereby releasing the plugging devices from the enclosure into the wellbore at a downhole location. A dispensing tool can include a container having an enclosure therein, the enclosure including a flexible material that contains the plugging devices, and an end of the enclosure being secured to a member displaceable by an actuator. The enclosure material is cut in response to displacement of the member by the actuator. A plugging device can include at least one body configured to engage an opening in the well and block fluid flow through the opening, and multiple fibers including staple fibers or filaments formed into yarn.

Abstract: A flow conveyed plugging device for use in a well, the device can include a body, and one or more lines extending outwardly from the body, each of the lines having a lateral dimension that is substantially smaller than a size of the body. A method of plugging an opening in a well can include deploying at least one flow conveyed plugging device into the well, the flow conveyed plugging device including a body and, extending outwardly from the body, at least one of the group consisting of: a) one or more fibers and b) one or more lines, the flow conveyed plugging device being conveyed by flow in the well into sealing engagement with the opening. Another flow conveyed plugging device can include a body, and fibers extending outwardly from the body. The flow conveyed plugging device degrades and thereby permits flow through an opening in the well.

Abstract: Some methods of producing hydrocarbons from a formation include pressurizing a formation by pumping fluid into a portion of a wellbore having one or more first fractures in fluid communication with the formation, while the formation is pressurized, restricting fluid communication between the formation and the wellbore via the first fracture(s), and, while fluid communication between the formation and the wellbore via the first fracture(s) is restricted, producing hydrocarbons from the formation via one or more second fractures of the wellbore that are in fluid communication with the formation. Some methods include, while fluid communication between the formation and the wellbore via the first fracture(s) is restricted, creating the second fracture(s).

Abstract: A device comprises: a container; a first fitting coupled to the container; and a second fitting coupled to the container, wherein the first fitting is configured for coupling to a first service port of a system and the second fitting is configured for coupling to a second service port of the system such that a fluid can travel from the first service port to the second service port through the container while the system is running, wherein the system comprises at least one of an air conditioning system or a refrigeration system.

Abstract: A magnetic core structure for a Linear Variable Differential Transducer (LVDT) comprising an elongate core of magnetic material mounted within a protective tube and means for positioning the core within the protective tube, the means for positioning comprising a ball provided within the protective tube at one end of the core, the ball being formed of an elastic material having a coefficient of thermal expansion selected to compensate the difference in elongation between magnetic core structure components caused by thermal expansion.

Abstract: Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. One or more perforations to create during a fracturing stage of a fracturing job at one or more corresponding perforation sites in a wellbore can be identified. The one or more perforations can be formed through one or more perforation devices disposed in the wellbore. Specifically, the one or more perforation devices can be selectively activated from a surface of the wellbore through a well intervention-less technique to selectively form the one or more perforations during the fracturing stage. Further, a volume of fracturing fluid can be pumped into the wellbore during the fracturing stage to form one or more first fractures in a surrounding formation through the one or more perforations.

Abstract: A flow conveyed plugging device for use in a well, the device can include a body, and one or more lines extending outwardly from the body, each of the lines having a lateral dimension that is substantially smaller than a size of the body. A method of plugging an opening in a well can include deploying at least one flow conveyed plugging device into the well, the flow conveyed plugging device including a body and, extending outwardly from the body, at least one of the group consisting of: a) one or more fibers and b) one or more lines, the flow conveyed plugging device being conveyed by flow in the well into sealing engagement with the opening. Another flow conveyed plugging device can include a body, and fibers extending outwardly from the body. The flow conveyed plugging device degrades and thereby permits flow through an opening in the well.

Abstract: Loss circulation material (LCM) and method for treating loss circulation in a wellbore in a subterranean formation, including placing the LCM having a solid body with permeable portions or pores into the wellbore to dispose the LCM at the loss circulation zone, and collecting solids onto the LCM at the loss circulation zone to form a barrier. The LCM may be applied at a loss circulation zone in a hydrocarbon reservoir section of the subterranean formation, and upon subsequent hydrocarbon production the collected solids may be dislodged by the produced hydrocarbon to allow for hydrocarbon production through the permeable portions or pores of the disposed LCM.

Abstract: A sealing element (10) for use in a fluid-carrying pipeline (16) comprising a substantially central core (14) surrounded by a coating (12). The outer coating (12) is adapted to perform a partial extrusion through an opening (15) in a pipeline wall (16) to seal the opening (15). The density of the sealing element (10) is substantially the same as the density of the fluid (11) in the pipeline (16). The coating (12) comprises a two-part epoxy putty, and the core (14) is formed from a deformable material. A method of making the sealing element is also disclosed.

Abstract: A dart for effecting wellbore operations has an inactivated position and an activated position wherein the exterior profile of the dart is changed when the dart is activated. The change in profile may be achieved by moving (for example, rotating) a portion of the dart relative to the remaining portion. When inactivated, the exterior profile allows the dart to pass freely through a valve. When activated, the dart cannot pass through the valve because the changed exterior profile is caught by the interior profile of the valve. Once caught, the dart creates a seal to open the valve when fluid pressure above the seal is increased. The dart can thus be used in multiple stage applications with valves having seats of the same size so that the dart can be selectively activated to engage a desired valve seat.

Abstract: A perf ball includes a first dissolvable component, an electronic racer and/or a matrix of tracer particles in a wellbore environment. The electronic tracer and at least some tracer particles in the matrix of tracer particles are releasable from the perf ball upon dissolution of the first dissolvable component in a wellbore environment. Some tracer particles in the matrix of tracer particles are dissolvable in oil. Some tracer particles in the matrix of tracer particles are dissolvable in aqueous medium. The electronic tracer can include a sensor and memory for recording properties of the wellbore environment, including any of pressure, temperature, fluid composition, or other environmental, physical, or chemical parameters.

Abstract: A method of plugging at least one undesired opening in a fluid vessel can include introducing one or more plugging devices into the vessel, conveying the plugging devices by flow to the opening, and blocking the flow through the opening with the plugging devices. A system for plugging at least one undesired opening in a fluid vessel can include a deployment apparatus configured to introduce one or more plugging devices into the vessel, a sensor that measures a physical parameter indicative of leakage from the vessel, and a controller that activates an actuator of the deployment apparatus in response to receipt from the sensor of an indication of leakage from the vessel.

Abstract: Provided is a method of treating a subterranean formation comprising: preparing a well servicing fluid comprised of a base fluid, a temporary compacted material wherein the temporary compacted material is a compacted organic acid; placing the well servicing fluid into a subterranean formation; and allowing the temporary compacted material to gradually dissolve.

Abstract: A plugging device can include a body configured to engage and substantially block flow through a passageway, and the body including a winding of at least one of fiber, line, rope, tube, filament, film, fabric, mesh and weave. A method of plugging a passageway can include releasing a plugging device into a fluid flow, thereby causing the plugging device to be carried by the fluid flow to the passageway, the plugging device including a body formed with at least one winding, and the plugging device engaging the passageway and thereby blocking the passageway. A well system can include a plugging device conveyed through a tubular string by fluid flow in the well, the plugging device including a body configured to engage and resist extrusion through a passageway in the well, the body including a winding, and in which the winding substantially blocks the fluid flow through the passageway.

Abstract: Low profile diverters for, and the use of such diverters in, fracing operations to stimulate production of oil and gas are capable of seating against and temporarily sealing perforations, even when frac fluid is being pumped at high rates and pressures, or in horizontal or highly deviated well bores, where conventional ball sealers cannot be reliably used because of high flow rates and pressures.

Abstract: A reverse rotary sprinkler drilling pipe system with anti-sticking function and its application method. This system comprises the front and rear drilling pipes which are arranged in sequence, a water spraying device, a rotary device. The rear drilling pipe is connected with an external drilling rig. The front and rear drilling pipes are respectively arranged with through holes in an inner axial direction. The water spraying device comprises a first cylinder and a connecting body, and symmetrical multiple groups of water spraying holes are arranged on the inner sidewall of the first cylinder. A limit block is arranged in the upper part of the inner sidewall. The connecting body is disposed with water conveyance hole which is connected with the through hole and the inner part of the first cylinder.

Abstract: Methods and systems for designing, monitoring, and/or performing acidizing treatments in subterranean formations are provided. In certain embodiments, the methods comprise: determining a wellbore pressure and a fluid flow distribution for an acidizing fluid introduced into a portion of a subterranean formation; determining a breakthrough pore volume at a plurality of depths in the formation to provide a PVBT curve; determining whether a slope of the PVBT curve at a point corresponding to a first flow rate of the acidizing fluid in the subterranean formation is indicative of a compact dissolution regime, e.g., is less than zero or a minimum point of a range of tolerance thereof; and, if so, identifying a second flow rate for introducing the acidizing fluid into the interval of the well bore that is greater than the first flow rate.

Abstract: Methods for treating a subterranean formation include providing a first treatment fluid comprising a plurality of degradable diverting agents, introducing the first treatment fluid into the subterranean formation via a wellbore, and allowing a portion of the plurality of degradable diverting agents to divert a flow of at least a portion of the first treatment fluid or a portion of a second treatment fluid from a first location within the wellbore to a second location within the wellbore. The plurality of degradable diverting agents includes a blend of polylactic acid (PLA) and an acid-soluble hard particulate. Compositions for treating a subterranean formation include the plurality of degradable diverting agents.

Abstract: Methods of preventing or minimizing communication between adjacent wells include providing a treatment fluid including a conformance chemical, a diverting agent, and a hydraulic cement, introducing the treatment fluid into a first well adjacent a second well, allowing the conformance chemical, the diverting agent, and the hydraulic cement to block fractures in the first well to prevent or minimize communication between the first well and the second well, stimulating the second well after blocking the fractures, and recovering a formation fluid from the first well, the second well, or both.

Abstract: Systems and methods for fracturing an interval of a subterranean formation to produce fluid from a reservoir through a wellbore. A treating fluid flows into the wellbore to create fractures in the formation. A flow constraint material is selectively flowed into the wellbore simultaneously with the treating fluid. A parameter of the formation is monitored to determine whether a formation system strain is within a range. When the formation system strain is out of the range, the flow of the flow constraint material is adjusted. The flow constraint material partially constrains the treating fluid from entering a fracture so as to at least partially redistribute the treating fluid to an another fracture or fractures.

Abstract: A process for plugging a wellbore, e.g., an oil or gas well, which comprises installing a backpressure ball device into the wellbore to increase the back pressure for better control when introducing cement or other liquid plugging medium to plug the wellbore. The device has a spherical shape with through bores and/or external channels in a geometric pattern. The external diameter of the sphere provides a shoulder of given diameter which, when the device is installed in a wellbore, comes to rest against a smaller diameter shoulder within the wellbore. The device may free fall for all or part of the way down the wellbore but is typically pumped down at least for the last part of its delivery to confirm by an increase in pump pressure that it has landed. Cement and other liquid may then be pumped through the backpressure ball device to the distal region of the well. The backpressure ball device may also be applicable for use in the operation of an oilfield by providing backpressure to actuate drive rods.

Abstract: The flow of a fluid may be diverted from a high permeability zone to a low permeability portion of a subterranean formation by use of particulates comprising a mixture of (i) at least one aliphatic polyester having the general formula of repeating units: where n is an integer between 75 and 10,000 and R is selected from the group consisting of hydrogen, alkyl, aryl, alkylaryl, acetyl, heteroatoms, and mixtures thereof; and (ii) at least one compound of the formula: or an anhydride thereof wherein: R1 is —COO—(R5O)y—R4 or —H; R2 and R3 are selected from the group consisting of —H and —COO—(R5O)y—R4; provided both R2 or R3 are —COO—(R5O)y—R4 when R1 is —H and further provided only one of R2 or R3 is —COO—(R5O)y—R4 when R1 is —COO—(R5O)y—R4 R4 is —H or a C1-C6 alkyl group; R5 is a C1-C6 alkylene group; and each y is 0 to 5.

Abstract: Fluid plugs as downhole sealing devices and methods include providing a stimulating fluid to a casing conduit that is defined by the production casing to stimulate a portion of a subterranean formation within which the production casing extends. The methods further may include providing a sealing fluid to the casing conduit, providing a sealing device to the casing conduit, and flowing the sealing fluid and the sealing device to a perforated section of the production casing. The methods further may include locating the sealing device on a perforation, generating a fluid plug within the perforated section of the production casing by increasing a viscosity of the sealing fluid, and retaining the sealing device proximate the perforation with the fluid plug.

Abstract: Low profile diverters for, and the use of such diverters in, fracing operations to stimulate production of oil and gas are capable of seating against and temporarily sealing perforations, even when frac fluid is being pumped at high rates and pressures, or in horizontal or highly deviated well bores, where conventional ball sealers cannot be reliably used because of high flow rates and pressures.

Abstract: A method of closing a fluid flow path in a wellbore is disclosed that in one non-limiting embodiment includes: supplying a flexible structure having a selected shape sufficient to seat on an opening of the fluid flow path, the flexible structure including pores of selected dimensions; determining seating of the flexible structure on the opening of the fluid flow path from a sensor measurement; and supplying a slurry containing a sealant to the flexible structure seated on the opening of the fluid flow path to plug the pores with the sealant to close the fluid flow path.

Abstract: A method for re-fracturing of wells having perforated casing that were previously fractured is provided. The method employs degradable ball sealers having a density near that of the injection fluid such that high seating efficiency of balls on perforations is attained. The balls degrade at varying rates, so that some intervals are opened for fracturing while other intervals are still blocked by ball sealers. After fracturing of an interval, the interval may by shut-off by ball sealers that degrade at a much slower rate or that do not degrade. The method may be applied to proppant fracturing or acid fracturing.

Abstract: A method of operations in a subterranean formation, including driving a pump with an electrically powered motor to pressurize fluid, inserting a tool into a wellbore that intersects the formation, and directing the pressurized fluid into the wellbore above the tool to push the tool into the wellbore.

Abstract: A system and method for use in used in oil and gas wellbores is provided. More specifically, the disclosure relates to barriers or seals used in downhole operations involving activities such as perforating operations and well abandonment operations. The system and method relate to sealing a borehole such as when a well is being abandoned at the end of its productive life. The embodiments are particularly applicable to boreholes containing casing with an inner wall and an outer wall wherein an annulus is formed between the outer wall of the casing and the borehole wall.

Abstract: In accordance with some embodiments of the present disclosure, a method of computational modeling for tracking ball sealers in a wellbore is disclosed. The method may include, for a time step, calculating a number of ball sealers to inject into a wellbore, injecting the ball sealers, determining a length of the wellbore occupied by a fluid, and computing a spacing between each ball sealer in the length of the wellbore occupied by the fluid. The method may include calculating a first position of a ball sealer, determining a velocity the ball sealer, and computing a second position of the ball sealer. The method may include recording a number of active ball sealers and open perforations in the wellbore, calculating a ball sealer skin per division, and determining a fluid flow rate. The method may include selecting parameters for a stimulation operation in the wellbore based on the fluid flow rate.

Abstract: A hydraulic fracturing ball sealer used in fracturing of shale formations. A preferred embodiment is constructed of a generally spherical core and a pair of hemispherical shells positioned about the core. The shells are secured to each other along an equatorial seam. The multilayer frac-ball provides a strong but machinable structure with a pliable outer surface that is corrosion resistant, has a specific gravity that allows it to float in the fracturing fluid, and is relatively easy and inexpensive to manufacture. The frac-ball of the present invention is a two piece metal and polymer design. A two-part embodiment comprises a polymer core with a metal case or shell. A layer of epoxy resin may be used to secure the shell to the core. Alternate embodiments include multiple layers of different materials, generally arranged concentrically within the spherical shape. The surface of the frac-ball may be smooth, scored, or serrated.

Abstract: A method for characterizing one or more properties of a geological formation including brine, the method including inputting at least one first property of the geological formation into an equation of state (EOS) model, the EOS model accounting for a high temperature effect on the brine; solving the EOS model to determine at least one second property of the geological formation; and outputting the at least one second property to a display device.

Abstract: A method for pre-emptively reducing the production of water in an oil and gas well is provided. In one embodiment, a drill-in fluid having a relative permeability modifier (RPM) capable of impeding the production of water is introduced into the wellbore during drilling operations. In a second embodiment, a completion fluid having a relative permeability modifier (RPM) capable of impeding the production of water is introduced into the wellbore during completion operations. The drill-in fluid or completion fluid may further include an organosilicon compound to increase flow resistance and extend the effective RPM permeability application range.

Abstract: An improved ball drop apparatus including an atmosphere-to-pressure frac ball injection chamber. A ball is first inserted into the atmosphere-to-pressure ball injection chamber from a ball feeding apparatus. The ball is then pushed into a pressure equalization section through a first seal pack. In a preferred embodiment, the pressure equalization section is connected to a pressure equalization apparatus and also to the wellbore through a second seal pack. Once the ball is injected into the pressure equalization section, the pressure equalization apparatus applies pressure, thereby causing the pressure of the pressure equalization section to increase until it reaches close to wellbore pressure. Once the pressures of the pressure equalization section and the wellbore are close, the atmosphere-to-pressure frac ball injection chamber and the frac ball are pushed through the second seal pack and into the wellbore, where the frac ball can be pumped downhole.

Abstract: In downhole treatments in the oilfield, ball sealers seated in perforations may not fully seal and may leak fluid through gaps and asperities between the balls and the perforations. A method is given for improving the sealing of ball sealers in perforations by adding a sealing agent that forms a plug in the gaps and severely restricts or eliminates fluid flow. The sealing agent is preferably degradable or soluble, malleable fibers slightly larger than the gaps. Optionally, the particles may be non-degradable, rigid, of different shapes, and smaller than the gaps but able to bridge them. Mixtures of sealing agents may be used. The sealing agent may be added with the ball sealers, after the ball sealers, or both.

Abstract: In downhole treatments in the oilfield, ball sealers seated in perforations may not fully seal and may leak fluid through gaps and asperities between the balls and the perforations. A method is given for improving the sealing of ball sealers in perforations by adding a sealing agent that forms a plug in the gaps and severely restricts or eliminates fluid flow. The sealing agent is preferably degradable or soluble, malleable fibers slightly larger than the gaps. Optionally, the particles may be non-degradable, rigid, of different shapes, and smaller than the gaps but able to bridge them. Mixtures of sealing agents may be used. The sealing agent may be added with the ball sealers, after the ball sealers, or both.

Abstract: A method of removing a corrodible downhole article having a surface coating includes eroding the surface coating by physical abrasion, chemical etching, or a combination of physical abrasion and chemical etching, the surface coating comprising a metallic layer of a metal resistant to corrosion by a corrosive material.

Abstract: In downhole treatments in the oilfield, ball sealers seated in perforations may not fully seal and may leak fluid through gaps and asperities between the balls and the perforations. A method is given for improving the sealing of ball sealers in perforations by adding a sealing agent that forms a plug in the gaps and severely restricts or eliminates fluid flow. The sealing agent is preferably degradable or soluble, malleable fibers slightly larger than the gaps. Optionally, the particles may be non-degradable, rigid, of different shapes, and smaller than the gaps but able to bridge them. Mixtures of sealing agents may be used. The sealing agent may be added with the ball sealers, after the ball sealers, or both.

Abstract: A method for placing ball sealers within a well formed within a subterranean formation for sealing holes in a casing of the well is carried out by performing at least one of two operations. The first operation involves providing a tag with at least one ball sealer or a carrier fluid containing the at least one ball sealer to facilitate monitoring of the location of the ball sealer. A tag monitoring device is provided within the well for monitoring the location of the tag. The ball sealer and carrier fluid with the tag are introduced downhole into the well. Information from the monitor device regarding the location of the tag is communicated to a remote monitoring location to the thereby provide an indication of the location of the tag within the well to a surface location. In the second operation a container is provided within the well at a known location downhole within the well. The container contains at least one ball sealer.

Abstract: Swellable ball sealers comprising swellable material are described. A swellable ball sealer may be used as a diversion agent by being suspended in a fluid injected into a wellbore and swelling once seated on a perforation such that the swellable ball sealer adapts to the shape of a perforation opening on which the swellable ball sealer has seated.

Abstract: Methods of controlling flow into a formation through the use of a stimulation valve in a tubular assembly installed in a well. Fluid is pumped into the formation through one or more ports in the stimulation valve. The stimulation valve defines a conduit for flow of fluids through the stimulation valve. The ports are adapted to allow flow of fluids between the conduit and the exterior of the stimulation valve and to receive a ball sealer for shutting off flow of fluids through the ports. The ports then are closed by introducing a plurality of ball sealers into the fluid. The fluid carries the ball sealers into the valve where they seat on and shut off flow of the fluid through the ports.

Abstract: A method of delivering a concentrated quantity of sealing elements to a leak site in a vessel includes deploying a flexible body of material and at least one sealing element into fluid flowing within the vessel upstream of the leak site. The body of material transports the sealing elements through the vessel to the leak site where the body of material is drawn to the leak by fluid flow created by a pressure differential at the leak site. The sealing element(s) are constrained by the body of material at the leak site such that the sealing element(s) become(s) entrained within the leak.

Abstract: In downhole treatments in the oilfield, ball sealers seated in perforations may not fully seal and may leak fluid through gaps and asperities between the balls and the perforations. A method is given for improving the sealing of ball sealers in perforations by adding a sealing agent that forms a plug in the gaps and severely restricts or eliminates fluid flow. The sealing agent is preferably degradable or soluble, malleable fibers slightly larger than the gaps. Optionally, the particles may be non-degradable, rigid, of different shapes, and smaller than the gaps but able to bridge them. Mixtures of sealing agents may be used. The sealing agent may be added with the ball sealers, after the ball sealers, or both.

Abstract: In one aspect the invention provides a ball injecting apparatus for releasing balls into the wellbore of a well. The apparatus comprises a body having an interior capable of housing one or more balls, at least one window in the body to allow for fluid communication between the body's interior and outside atmosphere. The window also provides for placement and removal of the balls into and out of the body's interior. An opening of suitable dimensions is provided on the body to allow the balls to exit the apparatus. A ball retaining and release mechanism retains and selectively releases the balls out the opening. The interior of the ball injecting apparatus is open to atmospheric pressure during operations. System and method aspects are also provided.

Abstract: High strength, low density ball sealer for sealing openings in oil or gas wells, such as perforations formed through the well casing or openings formed through slidable packers or sleeves received within a tubing string in the well, from the flow of a fluid injected into the well. The ball sealer is formed as having an inner core, and a metal matrix composite layer surrounding the core.

Abstract: High strength, degradable ball sealer for temporarily sealing off lower zones in a wellbore from the flow of a fluid injected into the well. The degradable ball sealer may also seal openings formed through slidable packers or sleeves received within a tubing string in the well, from the flow of a fluid injected into the well. The ball sealer includes an aluminum-based alloy matrix containing gallium, with graphitic carbon particulate and salt particulate homogeneously distributed within the aluminum-based alloy matrix.

Abstract: A multilayered ball sealer having a deformable layer. The multilayered ball sealer has an outer or intermediate layer that is deformable under pressure. In the former, the deformable layer may be water-soluble or hydrolysable. In the latter, the outer layer is a sheath that contains the deformable layer and adapts to its shape. A multilayered ball sealer may be used as a diversion agent by being suspended in a fluid injected into a wellbore and applying pressure to deform the shape of the intermediate layer such that the multilayered ball sealer adapts to the shape of a perforation opening on which the multilayered ball sealer has seated.

Abstract: Methods of controlling fluid loss, providing fluid diversion, or plugging a portion of a well bore using a treatment fluid including relatively insoluble borate material particulates that are placed into a subterranean formation to provide the desired action and then degrade over time in the subterranean formation in the presence of an aqueous fluid such as water.

Abstract: A method for placing ball sealers within a well formed within a subterranean formation for sealing holes in a casing of the well is carried out by performing at least one of two operations. The first operation involves providing a tag with at least one ball sealer or a carrier fluid containing the at least one ball sealer to facilitate monitoring of the location of the ball sealer. A tag monitoring device is provided within the well for monitoring the location of the tag. The ball sealer and carrier fluid with the tag are introduced downhole into the well. Information from the monitor device regarding the location of the tag is communicated to a remote monitoring location to the thereby provide an indication of the location of the tag within the well to a surface location. In the second operation a container is provided within the well at a known location downhole within the well. The container contains at least one ball sealer.

Abstract: A method for placing ball sealers within a well formed within a subterranean formation for sealing holes in a casing of the well is carried out by performing at least one of two operations. The first operation involves providing a tag with at least one ball sealer or a carrier fluid containing the at least one ball sealer to facilitate monitoring of the location of the ball sealer. A tag monitoring device is provided within the well for monitoring the location of the tag. The ball sealer and carrier fluid with the tag are introduced downhole into the well. Information from the monitor device regarding the location of the tag is communicated to a remote monitoring location to the thereby provide an indication of the location of the tag within the well to a surface location. In the second operation a container is provided within the well at a known location downhole within the well. The container contains at least one ball sealer.

Abstract: An apparatus and method are provided for substantially sealing an opening defined by a hydrocarbon well downhole component, wherein an interior portion of the downhole component is in fluid communication with a formation surrounding the hydrocarbon well. The apparatus includes a deformable plug adaptable to being injected into the wellbore and carried through the wellbore in a fluid. The fluid carrying the deformable plug can flow through the opening and the deformable plug is sized and configured such that at least a portion of the deformable plug can deform to the contour of the opening and seat in the opening. The deformable plug is capable of swelling, hardening, or compressing such that the deformable plug forms a substantially sealed relationship with the hydrocarbon well downhole component such that the interior portion of the downhole component ceases to be in fluid communication with the formation surrounding the well.