Abstract: In one aspect, a method of method of performing a wellbore operation is disclosed that in one embodiment may include: providing a device that includes a non-explosive energetic material configured to disintegrate when subjected to a selected energy; placing the device at a selected location in the wellbore to perform a selected function; and subjecting the device to the selected energy to disintegrate the device in the wellbore after the device has performed the selected function. In another aspect an apparatus for use in a wellbore is disclosed that in one embodiment may include a device placed in the wellbore at a selected location, wherein the device includes a non-explosive energetic material configured to disintegrate when subjected to a selected energy, and a source of the selected energy configured to subject the device to the selected energy in the wellbore to disintegrate the device.

Abstract: A permeable material compacting method includes positioning permeable material around a mandrel, rotating the permeable material about an axis of the mandrel, longitudinally moving at least one tapered surface against the permeable material and reducing a radial thickness of the permeable material between a surface of the mandrel and the at least one tapered surface.

Abstract: A permeable material compacting method includes feeding permeable material between at least one set of rollers, and decreasing a cross sectional area of the permeable material as it passes between the at least one set of rollers.

Abstract: A flow conduit may have at least one orifice, which conduit is in the vicinity of a flow source. The source is at least partially covered (and flow blocked by) an optional temporary coating or barrier (e.g. filter cake). The flow pathway between the orifice and the source is temporarily blocked with a degradable material. A delayed degradation material layer is present over or covering the degradable material. The delayed degradation material layer degrades at a rate slower than the degradable barrier. The degradable material and delayed degradation material layer disintegrate (e.g. via time, temperature, a solvent). The degradable material optionally produces a product that removes the temporary coating. The method is useful in one context of recovering hydrocarbons where the flow conduit is the casing or liner of the well and the flow source is a subterranean reservoir where the coating is filter cake.

Abstract: A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves one series of which can be put in the wide open position after run in for gravel packing and fracturing zones one at a time or in any desired order. These valves are then closed and another series of valves can be opened wide but with a screen material juxtaposed in the flow passage to selectively produce from one or more fractured zones. An annular path behind the gravel is provided by an offset screen to promote flow to the screened production port. The path can be a closed annulus that comes short of the production port or goes over it. For short runs an exterior screen or shroud is eliminated for a sliding sleeve with multiple screened ports that can be opened in tandem.

Abstract: A production system includes, a tubular having a plurality of sets of ports therethrough spaced longitudinally therealong positionable within a structure, at least one screen radial of the tubular defining an annulus between the structure and the at least one screen, at least one solids control mechanism configured to fill the annulus, and a plurality of flow restrictors.

Abstract: Wiper plugs or other shapes are made from shape memory foam in a size large enough to wipe or clean a tubular of a predetermined size. The plug or other shape is then reformed to a smaller dimension above its transition temperature and allowed to cool while holding that shape. The smaller shape allows delivery through a running string that is smaller than the tubular string to be wiped. Preferably before reaching the string to be wiped, the trigger is applied to get the wiper or other shape above its transition temperature where it then reverts to the prior larger dimension for effective wiping of the string that it will next pass through. The trigger can be well fluid temperature or composition, applied heat from the tubular, generated heat within the wiper or other shape, or heat released from agents introduced into the well acting alone or in conjunction with well fluids.

Abstract: Perforating devices, temporary dissolvable plugs, and dissolvable indicator devices for downhole tools all having at least one tracer are disclosed. Upon detonation of the perforating charge, dissolution of the temporary plug, or actuation of a downhole tool, the tracer is released and carried to the surface as an indictor to the operators of the well that the perforating charge detonated, the temporary plug dissolved, or the downhole tool actuated.

Abstract: Perforating devices, temporary dissolvable plugs, and dissolvable indicator devices for downhole tools all having at least one tracer are disclosed. Upon detonation of the perforating charge, dissolution of the temporary plug, or actuation of a downhole tool, the tracer is released and carried to the surface as an indictor to the operators of the well that the perforating charge detonated, the temporary plug dissolved, or the downhole tool actuated.

Abstract: A screen that conforms to the borehole shape after expansion is disclosed. The screen comprises a compliant outer layer that takes the borehole shape on expansion. The outer layer is formed having holes to permit production flow. The material that is selected preferably swells with prolonged contact to well fluids to further close off annular gaps after expansion. In an alternative embodiment, the screen is not expanded and the swelling of the material alone closes off annular gaps. The outer sleeve is placed over the screen and the screen is placed on a base pipe and initially expanded from within the base pipe to secure the components of the screen assembly for running downhole, while minimizing or eliminating any welding among the layers. A variety of expansion tools can be used to expand the screen or screens downhole.

Abstract: A fracturing operation is done in open hole. The annular space is spanned by telescoping members that are located behind isolation valves. A given bank of telescoping members can be uncovered and the telescoping members extended to span the annular space and engage the formation in a sealing manner. Pressurized fracturing fluid can be pumped through the telescoped passages and the portion of the desired formation fractured. In a proper formation, cementing is not needed to maintain wellbore integrity. In formations that need annular space isolation, the string in a preferred embodiment can have an external material that grows to seal the annular space in lieu of a traditional cementing operation.

Abstract: A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves one series of which can be put in the wide open position after run in for gravel packing and fracturing zones one at a time or in any desired order. These valves are then closed and another series of valves can be opened wide but with a screen material juxtaposed in the flow passage to selectively produce from one or more fractured zones. An annular path behind the gravel is provided by an offset screen to promote flow to the screened production port. The path can be a closed annulus that comes short of the production port or goes over it. For short runs an exterior screen or shroud is eliminated for a sliding sleeve with multiple screened ports that can be opened in tandem.

Abstract: A fracturing operation is done in open hole without annular space isolation. The annular space is spanned by extendable members that are located behind isolation valves. The extendable members can comprise a biodegradable plug that allows extension of the extendable members by application of pressure. With the plug remained in place, additional pressure can be delivered until at least a portion of the degradable material is pushed onto the surface of the formation. At least a portion of the pushed degradable material provides a seal between the end of the extendable members and the surface of the formation to allow pressure to build until the formation frac gradient is exceeded and the formation is fraced.

Abstract: A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves one series of which can be put in the wide open position after run in for gravel packing and fracturing zones one at a time or in any desired order. These valves are then closed and another series of valves can be opened wide but with a screen material juxtaposed in the flow passage to selectively produce from one or more fractured zones. An annular path behind the gravel is provided by an offset screen to promote flow to the screened production port. The path can be a closed annulus that comes short of the production port or goes over it. For short runs an exterior screen or shroud is eliminated for a sliding sleeve with multiple screened ports that can be opened in tandem.

Abstract: A fracturing operation is done in open hole. The annular space is spanned by telescoping members that are located behind isolation valves. A given bank of telescoping members can be uncovered and the telescoping members extended to span the annular space and engage the formation in a sealing manner. Pressurized fracturing fluid can be pumped through the telescoped passages and the portion of the desired formation fractured. In a proper formation, cementing is not needed to maintain wellbore integrity. In formations that need annular space isolation, the string in a preferred embodiment can have an external material that grows to seal the annular space in lieu of a traditional cementing operation.

Abstract: A device and system for controlling fluid flow into a wellbore tubular may include a flow path in a production control device and at least one in-flow control element along the flow path. A media in the in-flow control element adjusts a cross-sectional flow area of the flow path by interacting with water. The media may be an inorganic solid, a water swellable polymer, or ion exchange resin beads. A method for controlling a fluid flow into a wellbore tubular may include conveying the fluid via a flow path from the formation into a flow bore of the wellbore; and adjusting a cross-sectional flow area of at least a portion of the flow path using a media that interacts with water. The method may include calibrating the media to permit a predetermined amount of flow across the media after interacts with water.

Abstract: Devices and methods for setting a packer inside a wellbore with little appreciable reduction of the useable area of the wellbore. The outer casing or liner of the wellbore contains one or more integrated casing coupler joints having an increased diameter chamber portion. A large bore packing element is carried within the increased diameter chamber portion. The packing element may be selectively actuated to form a seal against an interior tubular member. Because the packing element is located within the chamber portion of the casing coupler, the packer may be set while saving useable cross-sectional area within the casing.

Abstract: A downhole annealing system includes a component to be annealed; a steam generating catalyst in proximity to the component; and a reactant fuel selectively communicative with the catalyst to produce an exothermic reaction and method.

Abstract: Devices and methods for setting a packer inside a wellbore with little appreciable reduction of the useable area of the wellbore. The outer casing or liner of the wellbore contains one or more integrated casing coupler joints having an increased diameter chamber portion. A large bore packing element is carried within the increased diameter chamber portion. The packing element may be selectively actuated to form a seal against an interior tubular member. Because the packing element is located within the chamber portion of the casing coupler, the packer may be set while saving useable cross-sectional area within the casing.

Abstract: Nanoparticle-treated substrates, such as screens, sand beds or proppant beds, may effectively filter and purify fluids such as waste water or fluids produced from a formation, as well as other liquids. When tiny contaminant particles in a fluid such as waste water flow contact the nanoparticle-treated substrate, the nanoparticles will capture and hold the tiny contaminant particles on the substrate due to the nanoparticles' surface forces, including, but not necessarily limited to van der Waals and electrostatic forces or other associative forces. Coating agents such as alcohols, glycols, polyols, vegetable oil, and mineral oils may help apply the nanoparticles to the surfaces of structures in the filter beds or packs.