A backup ring assembly has a plurality of radially offset ring members including an outermost ring member formed from plurality of axially extending segments. Each of the plurality of axially extending segments includes an outer surface. A first interlock member support is coupled to the outer surface of one of the plurality of axially extending segments of the outer most ring member. A second interlock member support is coupled to the outer surface of an another one of the plurality of axially extending segments of the outermost ring member. An interlock member includes a first end supported at the first interlock member support and a second end supported at the second interlock member support. The interlock member restrains radially outward expansion of the ring and circumferential expansion of a gap extending between the one of the axially extending segments and the another one of the axially extending segments.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 33/128 - Packers; Plugs with a member expanded radially by axial pressure
2.
A SINGLE-PHASE MICROEMULSION ADDITIVE FOR SEPARATION OF OIL AND WATER
A single-phase microemulsion additive may be introduced to a stream containing mixtures of or emulsions of oil and water in an effective amount to separate oil from the water in the stream and/or separating water from the oil in the stream. The single-phase microemulsion additive is formed by combining at least one demulsifier, at least one water clarifier, at least one surfactant, and optionally at least one solvent.
Communication methods and systems for communicating from a surface location to a downhole component in a borehole in an earth formation are described. The methods and systems include modulating, by a first device at the surface location, a fluid flow through a mud motor according to a predetermined pattern, the mud motor disposed in the borehole, the modulated fluid flow generating a mechanical movement variation pattern of at least a part of the mud motor, detecting, by a second device in the downhole component, the mechanical movement variation pattern, and demodulating the mechanical movement variation pattern to receive a signal that is related to the predetermined pattern.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
A downhole pump including a mandrel defining a passageway therein and defining an inlet to the passageway that allows fluid ingress to the passageway from an environment outside of the mandrel and defining an outlet from the passageway that allows fluid egress from the passageway, a blade extending from the mandrel and sized for a close clearance fit in a tubular into which the pump is intended to be used, the blade upon rotation of the mandrel causing a fluid flow regime in a direction across the blade, into the inlet, through the passageway, out of the outlet and back to the blade.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
5.
METAL-TO-METAL SEALED POWER CONNECTION FOR SUBMERSIBLE PUMP MOTOR
An electrical submersible well pump motor (21) has metal-to-metal sealing for the power cable electrical connection. A conductor passage (47) in the motor head (29) has a conical seat (53). A motor contact member (62) electrically connected with the motor is located in the conductor passage below the seat. A metal tube (35) has a lower portion that inserts into an upper portion of the conductor passage. A metal sealing ferrule (69) encircles the tube, and a compression nut (71) deforms the ferrule into sealing engagement with the seat and the tube. An electrical conductor (73) extending from the power cable (27) protrudes downward from the tube and has a conductor contact member (75) on a lower end. The motor contact member and the conductor contact member stab into partial engagement with each other, defining a gap (85) between terminal surfaces of the contact members that can close up during operation due to thermal growth.
H01R 4/30 - Clamped connections; Spring connections using a screw or nut clamping member
E21B 41/00 - Equipment or details not covered by groups
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
F16L 19/06 - Joints in which sealing surfaces are pressed together by means of a member, e.g. a swivel nut, screwed on, or into, one of the joint parts in which radial clamping is obtained by wedging action on non-deformed pipe ends
H01R 13/52 - Dustproof, splashproof, drip-proof, waterproof, or flameproof cases
H02K 5/22 - Auxiliary parts of casings not covered by groups , e.g. shaped to form connection boxes or terminal boxes
6.
BOTTOM HOLE ASSEMBLY FOR CUTTING AND PULLING A TUBULAR
A bottom hole assembly (BHA) incorporates a tubular cutter driven by a downhole motor. A scraper moves into a smaller tubular to clean an area where a spear will later be engaged to the cut tubular portion. The scraper has a relatively movable mandrel that allows straight through flow into the motor or closes flow to build pressure to a telescoping jack to exert a pull force on the cut tubular after the cut is made. The spear is articulated with mandrel manipulation to grab the cut segment and weight is set down to shift the mandrel in the scraper to allow pressure buildup with rig pumps turned on to retract the jack as the BHA is held with anchors in the larger tubular. The cut segment is pulled uphole to loosen it so it can be removed from the borehole.
E21B 31/16 - Grappling tools, e.g. tongs or grabs combined with cutting or destroying means
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
A bottom hole assembly (BHA) incorporates a tubular cutter driven by a downhole motor. A scraper moves into a smaller tubular to clean an area where a spear will later be engaged to the cut tubular portion. The scraper has a relatively movable mandrel that allows straight through flow into the motor or closes flow to build pressure to a telescoping jack to exert a pull force on the cut tubular after the cut is made. The spear is articulated with mandrel manipulation to grab the cut segment and weight is set down to shift the mandrel in the scraper to allow pressure buildup with rig pumps turned on to retract the jack as the BHA is held with anchors in the larger tubular. The cut segment is pulled uphole to loosen it so it can be removed from the borehole.
E21B 23/08 - Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 29/08 - Cutting or deforming pipes to control fluid flow
E21B 31/20 - Grappling tools, e.g. tongs or grabs gripping internally, e.g. fishing spears
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 37/04 - Scrapers specially adapted therefor operated by fluid pressure, e.g. free-piston scrapers
8.
TREATMENT METHODS USING AQUEOUS FLUIDS CONTAINING OIL-SOLUBLE TREATMENT AGENTS
A method of treating a well or a subterranean formation with an aqueous treatment fluid containing one or more oil-soluble, water-insoluble well treatment agents. The fluid includes an aqueous dispersion containing the well treatment agent in an amount from 25 to 60 weight percent. The volume average particle diameter of the oil-soluble well treatment agent in the fluid may be less than or equal to 2.5 microns. The fluid may further contain a water-soluble well treatment agent.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
C09K 8/70 - Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
C09K 8/88 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C09K 8/92 - Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
9.
PLUG FORMED FROM A DISINTEGRATE ON DEMAND (DOD) MATERIAL
A tubular includes an outer surface and an inner surface defining a passage. A plug is arranged in the tubular blocking the passage. The plug is formed from a disintegrating on demand (DOD) material. An ignition device is coupled to the plug. An excitation mechanism is selectively operatively associated with the ignition device. The excitation mechanism selectively activates the ignition device to break apart the plug.
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
An isolation plug including a support element having a first end, a second end, and an intermediate portion extending therebetween. At least one flexible wiper element is arranged at the first end. A frangible locator element is arranged at the first end spaced from the at least one flexible wiper element. A selectively deployable plug element is arranged at the second end.
A valve arrangement including a housing having a port, a closure member defining a bore, the bore being of a smaller flow area than an adjoining flow area to produce a lower pressure in flowing fluid therein than pressure in fluid flowing in the adjoining flow area, the closure member being disposed within the housing and movable between a closed position and an open position, a volume defined between the closure member and the housing, an opening in the closure member extending from the volume to the bore of the closure member to convey fluid pressure generated in the bore of the closure member to the volume thereby creating a lower pressure in the volume thereby biasing the closure member into a closed position.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/00 - Valve arrangements for boreholes or wells
F16K 3/24 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with sealing faces shaped as surfaces of solids of revolution with cylindrical valve members
An earth-boring tool comprising a body having first cutting elements mounted to an axially leading face, the first cutting elements each having a cutting face exposed to a height above the face of the body, the cutting faces of the first cutting elements back raked and facing a direction of intended rotation of the earth-boring tool. The earth-bring tool further comprises second cutting elements mounted to the axially leading face of the body adjacent first cutting elements in a cone region of the bit face, the second cutting elements each having a cutting face exposed to a height above the face of the body and configured for a shear-type cutting action, the cutting faces of the second cutting elements back raked to about a same or greater extent than the first cutting elements and generally facing the direction of intended rotation of the earth-boring tool.
A connector for a coiled tubing end anchors internally and seals externally. The anchor profile is split with a gap to clear an internal spline without need to remove the spline to allow a seal to enter the coiled tubing since the seal is mounted internally to a sleeve that envelops the end of the coiled tubing. Component relative rotation extends the internal anchor radially against the coiled tubing inner wall to secure the connection with the seal engaged to the coiled tubing outer wall.
F16L 19/07 - Joints in which sealing surfaces are pressed together by means of a member, e.g. a swivel nut, screwed on, or into, one of the joint parts in which radial clamping is obtained by wedging action on non-deformed pipe ends adapted for use in socket or sleeve connections
A sealing system for a flow channel comprises a mandrel; a swellable element disposed about the mandrel; and a swell control element disposed on a surface of the swellable element and configured to delay swelling of the swellable element; wherein the swell control element comprises a polymeric matrix that is impermeable to oil, water, or a combination thereof; and a channel inducer dispersed in the polymeric matrix, the channel inducer comprising carbon nanotubes, a hollow fiber, a degradable polymer, an oil swellable material, or a combination comprising at least one of the foregoing.
A system for use in corrosive environments includes a first tubular including a first connector portion, and a second tubular including a second connector portion. The first connector portion overlaps the second connector portion to form a connection joint. A magnesium element is arranged between the first connector portion and the second connector portion at the connection joint.
A well pump seal section housing (25) connects between a pump (13) and a motor (17). Upper and lower retainers (37, 59) at upper and lower ends of the housing have outward facing cylindrical walls (41, 61). bladder (45) has an interior in fluid communication with dielectric lubricant in the motor. Rigid upper and lower sleeves (51, 69) are bonded within upper and lower openings of the bladder. The sleeves slide over the cylindrical walls of the retainers and are sealed by seal rings (43, 63). Fasteners (57, 77) secure the sleeves to the cylindrical walls.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 41/00 - Equipment or details not covered by groups
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
A liner is cemented bottom up and then top down followed by setting the simultaneously set liner hanger/packer and releasing the running tool. In one embodiment the ported sub for top down cementing has ports opened and then closed with multiple dropped or pumped balls one of which lands in the running tool to set the hanger packer with pressure before running tool removal. A dart with a leading ball can follow the top down cement to close the ported sub and thereafter land in the liner hanger/packer to set it with pressure. A dart can lead the top down cement and open the ported sub followed by a second dart behind the top down cement to close the ported sub and land in the liner hanger/packer to set it and to release the running tool. The ported sub can be operated in other ways such as motors responsive to a remote signal.
E21B 33/138 - Plastering the borehole wall; Injecting into the formation
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
18.
ROTATABLE CUTTERS AND ELEMENTS FOR USE ON EARTH-BORING TOOLS IN SUBTERRANEAN BOREHOLES, EARTH-BORING TOOLS INCLUDING SAME, AND RELATED METHODS
Rotatable elements for use with earth-boring tools include a movable element and a stationary element. The movable element and stationary element include an index positioning feature that is configured to rotate the movable element as the movable element moves between a first axial position and a second axial position.
A linear selective profile actuation system including a traveling actuation member having a selective profile, the selective profile being resilient or rigid and possessed of a shoulder, a resource recovery tool having a tool profile, the tool profile being resilient or rigid, providing at least one of the selective profile or the tool profile is resilient, the tool profile being possessed of a seat, the tool profile and selective profile being configured to engage the shoulder and seat without resilient action from either the tool profile or selective profile if the selective profile is complementary to the tool profile or to resiliently pass the traveling actuation member if the selective profile is not complementary to the tool profile. A method for actuating a resource recovery tool. A resource recovery system including a borehole, a tubular string in the borehole, a resource recovery tool having a tool profile.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
Spring discs are rotationally locked to the mandrel are between pairs of actuation rings that feature a circumferential protrusion. On application of axial force release of a stored force from flexing, the protrusion engages a sloping portion of the spring disc and moves the sloping portion toward a more vertical orientation. Alternatively, a release of a stored force from flexing accomplishes the same result. Slots in the spring disc allow irregular growth to conform to surface irregularities of a surrounding surface. The discs can serve as anchors, centralizers or supports for a sealing element in a packer. Ends of fingers feature stiffeners to enhance strength. The discs can be stacked apart or together and oriented in the same or opposed directions. The can deliver an axial force when stacked and pushed toward flat and released.
A unique backup ring against ends of a sealing element features axial slots extending part way along a cylindrical segment of the backup ring. The slots end in rounded openings to relieve stress and a part of the cylindrical shape of the backup ring is solid. The slotted end of the cylindrical portion is tapered in section toward the end overlapping the sealing element. The face of the backup ring away from the sealing element is tapered and rides on an adjacent tapered surface away from the mandrel during the setting. The tapered seal end of the backup ring bends to reach the surrounding tubular before the balance of the cylindrical portion reaches the surrounding tubular. Extrusion along the mandrel is stopped by a mandrel seal on an adjacent wedge ring. The mandrel end of the backup ring has a peripheral stiffener to lend rigidity.
A valve device selectively communicates annulus pressure or pressure from a hydraulic circuit to an actuation piston of a borehole tool to directly or indirectly set the borehole tool. A valve member is held against spring bias by a retainer whose physical properties can be remotely changed to release the force of the bias to move the valve member which in turn moves an actuating piston to set the borehole tool. The compressive strength of the material can be impacted by electric current that directly or indirectly such as with the generation of heat results in weakening the retainer. The retainer material may be surrounded with a sleeve to enhance compressive strength until the remote signal is applied such as with wireline or electric line. Other property changes to the retainer are contemplated such as volume change, shape change, change in state or change in tensile or compressive strength.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
23.
CAPTURE METHOD FOR FLOW BACK RETRIEVAL OF BOREHOLE PLUG WITH A LOWER SLIP ASSEMBLY
A borehole plug or packer for treating is designed to be flowed back to a surface location after use. When the treatment is concluded pressure from above is relieved or lowered, and well fluid is flowed back, so that the plug or plugs disengages at slips designed to resist differential pressure from above. The application of differential pressure from below causes the lower slips to release one or more of such plugs in the hole into specialized sub surface or surface capture equipment so that well pressure is relieved before removal of the plugs from specialized subsurface or surface capture equipment. Packers or plugs are captured above, below or at a wellhead in a receptacle. Production ensues without milling with the captured plugs or packers in place or removed.
It has been discovered that contaminants such as metals and/or amines can be transferred from a hydrocarbon phase to a water phase in an emulsion breaking process by using a composition that contains water-soluble C5-C12 polyhy-droxy carboxylic acids, ammonium salts thereof, alkali metal salts thereof, and mixtures of all of these. The composition may also optionally include a mineral acid to reduce the pH of the desalter wash water. The method permits transfer of metals and/or amines into the aqueous phase with little or no hydrocarbon phase undercarry into the aqueous phase. Resolving the emulsion into the hydrocarbon phase and the aqueous phase occurs in a refinery desalting process using electrostatic coalescence. The composition is particularly useful in treating crude oil emulsions, and in removing calcium and other metals therefrom. The polyhydroxy carboxylic acid additionally inhibits metal corrosion of metal pipe or other equipment used in a crude unit.
C10G 17/02 - Refining of hydrocarbon oils, in the absence of hydrogen, with acids, acid-forming compounds, or acid-containing liquids, e.g. acid sludge with acids or acid-containing liquids, e.g. acid sludge
C10G 31/08 - Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by treating with water
C10G 32/02 - Refining of hydrocarbon oils by electric or magnetic means, by irradiation, or by using microorganisms by electric or magnetic means
25.
FLOW BACK RETRIEVAL METHOD FOR BOREHOLE PLUG WITH A LOWER SLIP ASSEMBLY
A borehole plug or packer for treating is designed to be flowed back to a surface location after use. When the treatment is concluded pressure from above is relieved or lowered, and well fluid is flowed back, so that the plug or plugs disengages at slips designed to resist differential pressure from above. The application of differential pressure from below causes the lower slips to release one or more of such plugs in the hole into specialized sub surface or surface capture equipment so that well pressure is relieved before removal of the plugs from specialized subsurface or surface capture equipment.
Adding a cationic starch and/or an anionic starch to a conventional demulsifier or water clarifier reduces activity of the resulting product without losing demulsifier or water clarifier performance.
METHODS OF FORMING SUPPORTING SUBSTRATES FOR CUTTING ELEMENTS, AND RELATED CUTTING ELEMENTS, METHODS OF FORMING CUTTING ELEMENTS, AND EARTH-BORING TOOLS
A method of forming a supporting substrate for a cutting element comprises forming a precursor composition comprising discrete WC particles, a binding agent, and discrete particles comprising Co, Al, and one or more of C and W. The precursor composition is subjected to a consolidation process to form a consolidated structure including WC particles dispersed in a homogenized binder comprising Co, Al, W, and C. A method of forming a cutting element, a cutting element, a related structure, and an earth-boring tool are also described.
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
C22C 29/02 - Alloys based on carbides, oxides, borides, nitrides or silicides, e.g. cermets, or other metal compounds, e. g. oxynitrides, sulfides based on carbides or carbonitrides
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
28.
MULTI-FREQUENCY ACOUSTIC INTERROGATION FOR AZIMUTHAL ORIENTATION OF DOWNHOLE TOOLS
An apparatus for detecting a location of an optical fiber having an acoustic sensor disposed subsurface to the earth includes an acoustic emitter configured to emit a first signal having a first frequency and a second signal having a second frequency that is higher than the first frequency, the first and second emitted acoustic signals being azimuthally rotated around the borehole and an optical interrogator configured to interrogate the optical fiber to receive an acoustic measurement that provides a corresponding first received signal and a corresponding second received signal. The apparatus also includes a processor configured to (i) frequency-multiply the first received signal to provide a third signal having a third frequency within a selected range of the second frequency, (ii) estimate a phase difference between the second received signal and the third signal, and (iii) correlate the phase difference to the location of the optical fiber.
A sealing system for a flow channel comprises a mandrel; a swellable element disposed about the mandrel; and a degradable polymeric element disposed on a surface of the swellable element and configured to delay swelling of the swellable element; wherein the degradable polymeric element comprises one or more of the following: polyurethane; cured cyanate ester; an epoxy; polyimide; unsaturated polyester; or nylon.
A lock ring fits into a housing recess defined by a sliding member such as a sleeve. The lock ring is loosely fitted in the recess when the sleeve is in an initial position. The lock ring is preferably smooth on an outer dimension and has a beveled end. The beveled end engages an internal taper in the housing if a force is placed on the sliding sleeve to return it toward the original position. Preferably the shifting of the sleeve to a ports open position places the ratchet on the sleeve in alignment with the lock ring to hold the sliding sleeve locked in the open position.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
31.
DUAL-WALLED COILED TUBING WITH DOWNHOLE FLOW ACTUATED PUMP
Dual-walled coiled tubing assemblies are used to dispose a flow actuated pump into a wellbore. Dual-walled coiled tubing assemblies include an inner coiled tubing string and an outer coiled tubing string.
An article comprising a carbon composite containing carbon microstructures having interstitial spaces among the carbon microstructures; and a binder disposed in at least some of the interstitial spaces; wherein the carbon microstructures comprise unfilled voids within the carbon microstructures; and the binder comprises one or more of the following: polytetrafluoroethylene; polyvinyl fluoride; polyvinylidene fluoride; polychlorotrifluoroethylene; perfluoroalkoxy alkane; fluorinated ethylene propylene; ethylene tetrafiuoroethylene; ethylene chlorotrifluoroethylene; a peroxide cured copolymer of tetrafiuoroethylene and propylene; a fluorocarbon rubber; perfluorocarbon rubber; or a perfluoropolyether.
C04B 35/52 - Shaped ceramic products characterised by their composition; Ceramic compositions; Processing powders of inorganic compounds preparatory to the manufacturing of ceramic products based on non-oxides based on carbon, e.g. graphite
A valve for a plug passage features opposed perforated magnetic discs that repel each other to stay apart allowing flow through the openings of the spaced discs. When a predetermined flow rate is exceeded, the magnetic repelling force is overcome and one disc moves toward the other to shut off flow as contact between the discs closed the openings between them. One way is to offset the openings and guide the moving disc axially while rotationally locking the moving disc. Another way is to spirally guide the moving disc so that openings initially aligned rotate out of alignment. One or more edge slots can be provided in each disc to sweep out debris that can settle between the discs that would otherwise impede the moving disc from contacting the stationary disc for passage closure.
A downhole tool including a housing, a first portion of a trigger mechanism disposed in the housing, a degradable-on-command component movably disposed within the housing, a second portion of the trigger mechanism disposed in the component, the component being configured to positionally respond to an external input to dispose the first portion and second portion in operational contact with one another resulting in an initiation of degradation of the degradable-on-command component. A method for removing a component of a downhole tool.
An additive comprising one or more C3-C12 hydroxycarboxylic acids and/or one or more C3-C12 hydroxycarboxylic acid salts may be added to an aqueous system having galvanized metallurgy or a carbon steel surface in an effective amount to passivate a galvanized coating on the metallurgy or to decrease white rust formation or other types of corrosion upon the galvanized metallurgy or carbon steel surface in an aqueous system. In a non-limiting embodiment, the C3-C12 hydroxycarboxylic acid or the C3-C12 hydroxycarboxylic acid salt additive may utilize the zinc in the galvanized coating to achieve passivation. The passivation may occur while the system is shut down or in service. The aqueous system may be or include a cooling tower, a cooling water system, and combinations thereof. The additive may be used with or in the absence of a phosphorous-containing compound.
C23F 11/18 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using inorganic inhibitors
36.
DOWNHOLE TOOLS HAVING CONTROLLED DEGRADATION AND METHOD
A downhole assembly includes a downhole tool including a degradable-on-demand material, the degradable-on-demand material including a matrix material, and a unit in contact with the matrix material, the unit including a core comprising an energetic material configured to generate energy upon activation to facilitate degradation of the downhole tool and, an activator disposed in contact with the core, the activator having a triggering system including an electrical circuit, an igniter in the electrical circuit arranged to ignite the energetic material, a sensor configured to sense a target event or parameter within the borehole, and a control unit arranged to receive sensed signals from the sensor and to deliver a start signal to the electrical circuit in response to the sensed signals indicating an occurrence of the target event or parameter wherein, after the start signal is delivered from the control unit, the electrical circuit is closed and the igniter is initiated.
A milling apparatus for cutting a tubular in a wellbore includes a cutting element on a tool body configured to cut the tubular in a wellbore when the cutting element is activated when the tool is moving upward inside the tubular. The cutting element cuts the tubular to form cuttings that fall into an annulus between the tubular and the wellbore. An agitator below the cutting element agitates the cuttings in the annulus to aid the cuttings to move from the annulus into the wellbore below the milling apparatus.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
A multilayered unit includes a core comprising an energetic material and an activator; a support layer disposed on the core; and a protective layer disposed on the support layer, wherein the support layer and the protective layer each independently comprises a polymeric material, a metallic material, or a combination comprising at least one of the foregoing, provided that the support layer is compositionally different from the protective layer. The multilayered unit can be embedded in a component, attached to a component, or disposed between two components of a downhole assembly. The downhole assembly containing the multilayered unit has controlled disintegration in a downhole environment.
The present disclosure provides a formulation and methods for simultaneously dissolving metal sulfide scales, inhibiting acid gas corrosion, and inhibiting the formation of calcite and barite in a system having low or high shear stress conditions due to fluid movement, in which the formulation contains a THP+ salt, one or more corrosion inhibitors, one or more scale inhibitors, and one or more acid corrosion inhibitors. The formulation may be applied to the system in diluted or undiluted form, and continuously or in batch style.
C10G 75/02 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of corrosion inhibitors
A method of separating mature fine tailings from a suspension comprising mature fine tailings and water, the method comprising: introducing a polymer flocculent into the suspension such that the polymer flocculent interacts with the mature fine tailings, the polymer flocculent comprising an anionic organic polymer with a molecular weight in the range from 30,000 - 50,000 daltons.
A method of controllably disintegrating a downhole article comprises disposing the downhole article in a downhole environment, the downhole article containing a matrix material; a first chemical; and a second chemical physically isolated from the first chemical, and allowing the first chemical to contact and react with the second chemical generating an acid, a salt, heat, or a combination comprising at least one of the foregoing that accelerates the degradation of the matrix material in a downhole fluid.
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
A bottom hole assembly for performing a borehole treatment has a plurality of ported valve housings where the housings have an assembly of shifting sleeves. The first sleeve is shifted uphole to open the port in the housing and lock the first sleeve in the ports open position. A second sleeve in the same housing is shifted in the same direction as the first sleeve to close the ports in the housing. The second sleeve has profiles for shifting it up to close the housing ports and back down to reopen the housing ports after closing them.
An embodiment of a communication system for communicating between a wired pipe string in a borehole and a surface location includes at least a first wired pipe downhole component and a second wired pipe downhole component in the wired pipe string, a coupler configured to transmit a transmission signal between the first wired pipe downhole component and the second wired pipe downhole component, and a wireless transmission assembly in at least one of the first wired pipe downhole component and the second wired pipe downhole component. The wireless transmission assembly is configured to wirelessly transmit a wireless transmission signal to a receiver antenna, and the receiver antenna is disposed at the surface location and configured to receive the wireless transmission signal.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
H04Q 9/00 - Arrangements in telecontrol or telemetry systems for selectively calling a substation from a main station, in which substation desired apparatus is selected for applying a control signal thereto or for obtaining measured values therefrom
44.
DOWNHOLE TOOLS AND METHODS OF CONTROLLABLY DISINTEGRATING THE TOOLS
A method of controllably disintegrating a downhole article comprises disposing a first article in a downhole environment, the first article being the downhole article to be disintegrated; disposing a second article in the downhole environment after the first article is disposed, the second article carrying a device, a chemical, or a combination comprising at least one of the foregoing; and disintegrating the first article with the device, chemical, or the combination comprising at least one of the foregoing from the second article.
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
A method of making a stator includes positioning an inner tubular member having an inner surface within an outer tubular member, installing a rigid mandrel within the inner tubular member, and applying a compressive force to at least one of the inner tubular member and the outer tubular member.
H02K 15/02 - Methods or apparatus specially adapted for manufacturing, assembling, maintaining or repairing of dynamo-electric machines of stator or rotor bodies
46.
ARRANGEMENT AND METHOD FOR DEPLOYING DOWNHOLE TOOLS TO LOCATE CASING COLLAR USING XY MAGNETOMETERS
A method and apparatus for locating a collar of a casing of a wellbore is disclosed. A sensor for measuring a magnetic field is conveyed through the casing on a tool string. A physical model is formed of a process of obtaining a magnetic measurement of the casing with the sensor. A simulation of the physical model is run through a processor to select a design parameter of the tool that allows for using the sensor at a determined value of an operational parameter for obtaining the measurement at a selected signal-to-noise ratio. The tool is conveyed into the wellbore and the sensor set to the determined value of the operational parameter. The magnetic measurement of the casing is obtained using the sensor, and the collar is located using the obtained magnetic measurement.
A downhole assembly comprises a first article; and a second article having a surface which accommodates a surface shape of the first article, wherein the first article is configured to provide a chemical, heat, or a combination thereof to facilitate the disintegration of the second article. A method comprises disposing a second article in a downhole environment; disposing a first article on the second article; the second article having a surface which accommodates a surface shape of the first article; performing a downhole operation; and disintegrating the first article to provide a chemical, heat, or a combination thereof that facilitates the disintegration of the second article.
An array of sliding sleeve valves are uniquely addressable without control lines or wires to open for a treatment and then close and then selectively open for production. The discrete movements employ an available pressure source such as tubing pressure and change the piston areas on opposed sides of a sliding sleeve valve to get the desired movements. Access valves to tubing pressure can be actuated in a desired sequence with signals such as acoustic or electromagnetic, for example. Access to one piston area that communicates opposed and offsetting piston areas to the tubing hydrostatic can be achieved with a straddle tool breaking a rupture disc. The piston is then in pressure balanced and can be moved in a desired direction with the straddle tool straddling access locations to the piston from above or below.
A method of treating a first bore and at least one second bore connected to the first bore in one downhole trip includes guiding a treating tool including a seal assembly defining and a shroud extending about the seal assembly downhole, guiding the seal assembly and the shroud along a diverter positioned near an intersection of the first bore and the at least one second bore into the at least one second bore, shifting the shroud relative to the seal assembly exposing the seal assembly in the at least one second bore, performing a first treatment in the at least one second bore, positioning the seal assembly and the shroud uphole of the diverter, passing the seal assembly through an opening in the diverter having a diverter opening, and performing a second treatment in the first bore.
A one trip bottom hole assembly allows setting and testing a plug and release from the plug. Cement can be pumped onto the plug, after the BHA is raised, to an extent to meet local regulatory requirements. The cutter spear combination can be activated with pressure built on a second dropped ball larger than the first ball to release the blades for extension with fluid circulation. The circulation path through the spear is opened using pipe manipulation during the spear setting sequence. The cuttings from severing the tubular fall onto the cement. The spear is set with string manipulation as the drill string rotates the blades while maintaining the string under tension. The spear can be released and repositioned for the top of the string to facilitate removal and disassembly at the surface. All the above described operations are accomplished with a single trip into the hole.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
Systems, tools, and methods for optimizing fracturing schedules located along a horizontal wellbore include obtaining drilling cuttings during a drilling operation representative of a predetermined interval of the horizontal wellbore, performing at least one analytical process on the obtained drilling cuttings to determine at least one geomechanical property of the interval of the obtained drilling cuttings for the interval, generating a formation analysis estimation for the interval from the, wherein the formation analysis estimation comprises at least one of (i) a brittleness of the formation at the interval or (ii) a minimum horizontal stress of the formation at the interval, and based on the formation analysis estimation, at least one of (i) configuring a super-stage for deployment to the interval to perform a fracturing operation or (ii) designing a fracturing schedule to be performed to frac the formation at the interval.
A method of making a thin film substrate involves exposing carbon nanostructures to a crosslinker to crosslink the carbon nanostructures. The crosslinked carbon nanostructures are recovered and disposed on a support substrate. A thin film substrate includes crosslinked carbon nanostructures on a support substrate. The crosslinked carbon nanostructures have a crosslinker between the carbon nanostructures. A method of performing surface enhanced Raman spectroscopy (SERS) on a SERS-active analyte involves providing a SERS-active analyte on such a thin film substrate, exposing the thin film substrate to Raman scattering, and detecting the SERS-active analyte.
A downhole assembly comprises a disintegrable article that includes a matrix material; an energetic material configured to generate energy upon activation to facilitate the disintegration of the disintegrable article; and a sensor. A method of controllably removing a disintegrable downhole article comprises disposing the downhole article in a downhole environment; performing a downhole operation; activating the energetic material; and disintegrating the downhole article.
Methods, systems, devices, and products for downhole operations. Embodiments include downhole tools comprising an outer member configured for conveyance in the borehole; a pressure barrel positioned inside the outer member; a substantially cylindrical pod positioned inside the pressure barrel; and at least one downhole electronic component mounted between the exterior surface and the frame. The pod comprises at least one rigid outer surface forming an exterior surface of the pod and supported by a central frame extending across a diameter of the pod, such as a plurality of outer rigid surfaces. The pod may include a plurality of coupled rigid elongated semicircular metallic shells, wherein each shell of the plurality comprises a rigid outer surface of the plurality of outer rigid surfaces. Each of the at least one downhole electronic component may be sealingly enclosed within a corresponding shell.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 49/00 - 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
55.
DOWNHOLE ASSEMBLY INCLUDING DEGRADABLE-ON-DEMAND MATERIAL AND METHOD TO DEGRADE DOWNHOLE TOOL
A downhole assembly includes a downhole tool including a degradable-on-demand material and a triggering system. The degradable-on-demand material includes a matrix material and an energetic material configured to generate energy upon activation to facilitate the degradation of the downhole tool. The triggering system includes an igniter arranged to ignite the downhole tool, an electrical circuit, and a pre-set timer. In an open condition of the circuit the igniter is not activated, and in a closed condition of the circuit the igniter is activated. The pre-set timer is operable to close the electrical circuit after a pre-set time period.
A downhole assembly includes a downhole tool including a degradable-on-demand material including: a matrix material; and, an energetic material configured to generate energy upon activation to facilitate the degradation of the downhole tool; and, a triggering system including: an electrical circuit having an open condition and a closed condition, the electrical circuit configured to be in the closed condition after movement of an object downhole that engages directly or indirectly with the triggering system; and, an igniter within the electrical circuit, the igniter arranged to ignite the downhole tool in the closed condition of the electrical circuit. In the open condition of the electrical circuit the igniter is inactive, and in the closed condition of the electrical circuit the igniter is activated.
A downhole assembly arranged within a borehole includes a downhole tool including a degradable-on-demand material, the degradable-on-demand material including: a matrix material; and, an energetic material configured to generate energy upon activation to facilitate the degradation of the downhole tool; and, a triggering system including: an electrical circuit; an igniter in the electrical circuit arranged to ignite the energetic material; a sensor configured to sense a target event or parameter within the borehole; and, a control unit arranged to receive sensed signals from the sensor and to deliver a start signal to the electrical circuit in response to the sensed signals indicating an occurrence of the target event or parameter; wherein, after the start signal is delivered from the control unit, the electrical circuit is closed and the igniter is initiated.
A well fluid particle screen assembly includes a base pipe having first and second pipe segments. First and second sets of perforations are located in sidewalls of the first and second pipe segments. First and second screens are mounted around the first and second pipe segments. A second pipe segment valve mounted to the second pipe segment has a closed position blocking well fluid flow through the second set of perforations. The second pipe segment valve has a pressure area acted on by a well fluid pressure differential. When reaching a threshold, the pressure differential causes the second pipe segment valve to move from the closed position to an open position. A retainer retains the second pipe segment valve in the closed position until the threshold is reached.
An electrical submersible well pump assembly (11) includes an electrical motor (21) for driving a pump (17). A pressure compensating chamber (38) contains a dielectric lubricant (37) in fluid communication with an interior of the motor. A movable pressure compensating element (47) has a first side in contact with the lubricant in the chamber. Movement of the element relative to the chamber causes a change in volume of the chamber. An electrical drive mechanism (59, 61) is connected with and moves the element. A controller (55) senses a pressure difference between the lubricant pressure and the well fluid pressure and operates the drive mechanism in response. The element may be a piston (47), a bellows (71) or telescoping tubes (91, 93).
BP EXPLORATON OPERATING COMPANY LIMITED (United Kingdom)
Inventor
Curry, David A.
Pessier, Rudolf Carl
Spencer, Reed W.
Kuesters, Andrew
Wingate, John
Abstract
Methods of drilling earth formations may involve removing a portion of an underlying earth formation utilizing cutting elements of an earth-boring drill bit. A rotational speed of the drill string may be sensed utilizing a first sensor. A rate of penetration of the drill string during advancement of the earth-boring drill bit may be sensed utilizing a second sensor. An instantaneous average depth of cut of cutting elements of the earth-boring drill bit may be determined utilizing a control unit to calculate the instantaneous average depth of cut based on a sensed rotational speed of the drill string and a sensed speed of advancement of the drill string. The weight on the earth-boring drill bit may be increased utilizing the drawworks when the instantaneous average depth of cut is less than the predetermined minimum depth of cut.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A zone to be treated comprises a plurality of sliding sleeve valves. The sleeve defined opposed chambers charged with pressurized fluid on opposed sides of the sleeve. Valves responsive to a remote signal with no borehole intervention change the pressure balance on the sleeve to get it to open from a closed position and then close and then to reopen for production. One way this is done is by sequential pressure bleeding off from the opposed chambers. A zone having multiple such valves can be treated without need for dropping balls and subsequent milling out, which allows production to commence sooner with reduced restrictions to flow from the ball seats and without the debris associated from a milling operation.
Systems, methods and apparatuses to aid with directional drilling through a subterranean formation are described. A model is provided that is indicative of: (i) one or more frictional forces at one or more contact points of the BHA and a wall of a non-linear borehole through a subterranean formation, (ii) one or more internal torques of the BHA between the one or more contact points, and (iii) one or more internal torques of the drillstring between the one or more contact points. Based on the model, a toolface severity is determined for the drilling system, the toolface severity corresponding to a change in angular deflection for a change in applied weight-on-bit (WOB) of the BHA. A design is selected for the drilling system based on a comparison of the toolface severity to another toolface severity for a different design. Drilling may be performed by a drilling system having a bottomhole assembly (BHA) optimized to reduce fluctuations in toolface orientation along a non-linear borehole.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A dual telemetric coiled tubing running string for disposing a bottom hole assembly into a wellbore. The dual telemetric coiled tubing running string includes a string of coiled tubing which defines a flowbore along its length, an electrical wire conduit disposed within the flowbore, and an optic fiber disposed within the flowbore.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A bottom hole assembly (BHA) contains a motor and a section mill for milling in an uphole direction after blade extension with circulating fluid through the BHA. Below the section mill is sensing equipment to detect location of a bridge formed by the cuttings or swarf from the section mill. A secondary mill oriented for cutting in a downhole direction is located at the bottom of the BHA for use in removal of the bridge. The sensing equipment delivers in real time data as to the density of the bridge so that decisions to interrupt the section milling and to lower the secondary mill to the bridge can be made in real time. Cement is pumped and displaced by a wiper plug to plug and abandon the hole.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
A ball dropping system includes a ball retention feature; an ejection arrangement blocked from activating in a first condition of the ball dropping system, activatable in a second condition of the ball dropping system, and activated to eject a ball from the ball dropping system that is releasably secured by the ball retention feature in a third condition of the ball dropping system; and, a setting sleeve movable from a first position to a second position with respect to the ejection arrangement, the setting sleeve having the first position to block the ejection arrangement from activating in the first condition of the ball dropping system, and the setting sleeve movable to the second position to render the ejection arrangement activatable in the second condition of the ball dropping system.
A fishing tool for a fishing arrangement to remove a stuck fish or object from a wellbore. The fishing tool includes an overshot housing which defines an interior chamber. An inflatable bladder element resides within the interior chamber and is inflatable radially inwardly to capture a portion of the stuck fish. The fish is removed as the fishing arrangement is pulled out of the wellbore.
A thermal load based automatic valve arrangement including an actuator responsive to fluid temperature flowing through the arrangement, a closure member operably connected to the actuator, and a seat receptive to the closure member to prevent or restrict fluid flow through the arrangement in a first direction when actuated while still allowing fluid flow in a second direction. A method for controlling steam movement in a production string of a SAGD installation including sensing with an actuator, temperature of fluid moving through a valve arrangement, automatically adjusting the valve arrangement pursuant to thermal load on the actuator.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
F16K 17/38 - Safety valves; Equalising valves actuated in consequence of extraneous circumstances, e.g. shock, change of position of excessive temperature
F16K 31/64 - Operating means; Releasing devices responsive to temperature variation
F16K 31/68 - Operating means; Releasing devices responsive to temperature variation actuated by fluid pressure or volumetric variation in a confined chamber
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
A packer includes a body formed from an elastic composite material having one of a one -dimensional elastic structure, a periodic elastic structure, and a random elastic structure and a filler material. And a resource exploration/recovery system includes a surface portion, and a downhole portion including a plurality of tubulars, wherein they includes a packer comprising a body formed from an elastic composite material having one of a one -dimensional elastic structure, a periodic elastic structure, and a random elastic structure.
A milling and scraping tool for preparing a borehole to be plugged includes a tool body including a first end, a second end, and an intermediate portion extending therebetween and a milling system arranged between the first end and the second end. The milling system includes one or more selectively deployable milling blades. The one or more selectively deployable milling blades is shiftable between a retracted position and a deployed position. A scraping system IS arranged on the tool body. The scraping system includes a plurality of selectively deployable scraping blades selectively deployable from a retracted position to a deployed position.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
A system and method for confirming ignition of a fuel source in a wellbore is disclosed. The system includes a tool, a fuel source associated with the tool, a control unit to ignite the fuel source, and a sensor to receive an ignition parameter.
E21B 41/00 - Equipment or details not covered by groups
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
A cutting element comprises a supporting substrate exhibiting a three-dimensional, laterally elongate shape, and a cutting table of a poly crystalline hard material attached to the supporting substrate and comprising a non-planar cutting face. An earth-boring tool and method of forming an earth-boring tool are also described.
An apparatus for drilling directional wellbores is disclosed that in one non-limiting embodiment incudes a drive for rotating a drill bit, a deflection device that enables a lower section of a drilling assembly to tilt about a member of the deflection device within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and at least one seal that isolates at least a surface of the member from outside environment. The at least one seal is lubricated by a sealed hydraulic unit
An apparatus for drilling a directional wellbore is disclosed that in one non-limiting embodiment includes a drive for rotating a drill bit, a deflection device that enables a lower section of the drilling assembly to tilt about a member of the deflection device within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and a tilt sensor that provides measurements relating to tilt of the lower section. A controller determines a parameter of interest relating to the tilt for controlling drilling of the directional wellbore.
An apparatus for drilling a directional wellbore is disclosed that in one non-limiting embodiment includes a drive for rotating a drill bit, a deflection device that enables a lower section a drilling assembly to tilt within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and a sensor that provides measurements relating a direction of the drilling assembly for drilling the wellbore along a desired direction.
Both organic deposits and inorganic deposits in a wellbore are simultaneously removed from a wellbore by contacting the deposits with a single phase fluid for an amount of time effective to simultaneously disperse the organic deposits and dissolve the inorganic deposits, where the single phase fluid includes least one solvent, at least one surfactant, at least one co-solvent, and at least one scale dissolver. The method further involves at least partially removing the organic deposits and inorganic deposits from the wellbore. In an embodiment where it is not necessary to remove inorganic deposits, the scale dissolver may be omitted.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
76.
AMINE DETECTION USING SURFACE ENHANCED RAMAN SPECTROSCOPY WITH FUNCTIONALIZED NANOPARTICLES
A method of analyzing a selected refinery chemical at a low concentration comprises contacting a sample with functionalized metallic nanoparticles that contain metallic nanoparticles functionalized with a functional group comprising a cyano group, a thiol group, a carboxyl group, an amino group, a boronic acid group, an aza group, an ether group, a hydroxyl group, or a combination comprising at least one of the foregoing; radiating the sample contacted with the functionalized metallic nanoparticles with electromagnetic radiation at a selected energy level; measuring a Raman spectrum emitted from the sample; and determining the presence or a concentration of a selected refinery chemical in the sample from the Raman spectrum.
A downhole tool for controlling the flow of a fluid in a wellbore includes a component that comprises: a cementitious material; an aggregate; and a ductility modifying agent comprising one or more of the following: an ionomer; a functionalized filler; the functionalized filler comprising one or more of the following: functionalized carbon; functionalized clay; functionalized silica; functionalized alumina; functionalized zirconia; functionalized titanium dioxide; functionalized silsesquioxane; functionalized halloysite; or functionalized boron nitride; a metallic fiber; or a polymeric fiber.
An arrangement for accelerating a workpiece including a system inductor configured to be supplied a current, a workpiece positioned magnetically proximate to the system inductor, a workpiece inductor associated with the workpiece and configured to magnetically interact with the system inductor. A method for moving a workpiece in a magnetic pressure arrangement comprising increasing inductance of a workpiece subsystem of the arrangement by disposing a workpiece inductor at the workpiece. A method for moving a workpiece in a magnetic pressure system comprising tuning one or more of a resistor, capacitor or inductor of the system to adjust a phase angle of a magnetic pressure produced in the system.
A pin whose movement triggers setting of the borehole tool, is initially held by a collet that is supported off a surrounding housing. A spring is supported off the pin and would push a housing that locks the collet to the pin axially to unsupport the collet but for the presence of a Kevlar® wire that has an associated heater. The wire pulls the housing that locks the collet against the spring bias and has an end attached to the pin. Melting the wire allows the spring to move the housing that traps the collet to the pin. At that point hydrostatic pressure can move the pin to either open a port on the borehole tool to set it hydro statically or to move an actuation rod attached to the pin to set the borehole tool mechanically or with a combination of mechanical and hydraulic force.
An apparatus for applying a magnetic pressure to a work piece includes an inductor configured to be disposed in proximity to the work piece and a controller electrically connected to the inductor and configured to control a supply of electrical power in order to output a first voltage over a selected frequency range to determine a frequency that provides a maximum current or a frequency that provides a current within a selected range of the maximum current to the inductor.
An embodiment of a method for evaluating a schedule for removing a core sample includes generating a model of the core by applying a value of each of the input parameters, one or more of the input parameter values associated with an uncertainty range, and defining a proposed tripping schedule, and performing an evaluation including applying the proposed tripping schedule and a set of expected input parameter values to the model, estimating a core parameter and determining whether the tripping schedule is predicted to be successful by comparing the core parameter to selected core damage criteria. The method also includes iteratively repeating the evaluation, each evaluation being performed using a different combination of input parameter values than any other evaluation, and calculating a probability of success (POS) of the proposed tripping schedule based on a number of evaluations that result in the tripping schedule being predicted to be successful.
E21B 49/02 - 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 by mechanically taking samples of the soil
E21B 41/00 - Equipment or details not covered by groups
82.
METHOD AND APPARATUS FOR BENDING DECOUPLED ELECTRONICS PACKAGING
An apparatus for protecting an electronics module used in a borehole may include an enclosure disposed along a drill string. The electronics module may be attached to the enclosure by at least one joint. The at least one joint allows a predetermined bending between the electronics module and the enclosure that does not mechanically overload the electronics module. In some embodiments, the joint may be a ball joint.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 41/00 - Equipment or details not covered by groups
A test sub having a housing with a first end, a second end, a bore, and an exterior portion of the housing including a coiled tubing connector may be used to test a connection with coiled tubing. The test sub includes a valve positioned within the bore. The second end of the housing may be inserted into coiled tubing and fluid may be pumped into the housing to test the connection between the connector and the coiled tubing. The test sub may be a housing that may be attached to a coiled tubing connector already connected to coiled tubing. A rod within the housing may be moved to an inserted position permitting communication between a pressure port of the housing and an exterior port of the coiled tubing connector. Fluid may be pumped into the pressure port to test the connection between the coiled tubing connector and the coiled tubing.
A method of controlling drill bit trajectory in a subterranean formation includes receiving drilling parameters for operating a specific bottomhole assembly (BHA), constructing, with a computer processor, a directional drill-ahead simulator including a computer model of the BHA and the subterranean formation, calculating axial motion and lateral motion of a drill bit connected to a bottom end of the BHA using formation parameters and drilling parameters, predicting bit walk of the drill bit by accounting for and calculating contact forces and frictional forces between the BHA and a wall of a borehole in the subterranean formation using the computer model of the BHA, and determining an adjusted drill bit traj ectory to account for the predicted bit walk. The method includes determining adjusted drilling parameters for operating the BHA to substantially follow the adjusted drill bit trajectory and operating the BHA according to the adjusted drilling parameters.
E21B 41/00 - Equipment or details not covered by groups
E21B 44/04 - Automatic control of the tool feed in response to the torque of the drive
E21B 44/06 - Automatic control of the tool feed in response to the flow or pressure of the motive fluid of the drive
E21B 45/00 - Measuring the drilling time or rate of penetration
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
85.
METHOD OF ENHANCING FRACTURE COMPLEXITY USING FAR-FIELD DIVERT SYSTEMS
A method of stimulating production of hydrocarbons from a subterranean formation penetrated by a wellbore comprises: pumping an aqueous fluid having a divert system comprising (i) dissolvable diverter particulates and (ii) proppant, the dissolvable diverter particulates comprising a compound of the formula: or an anhydride thereof wherein: Ri is ¨000¨(R50)y¨R4 or ¨H; R2 and R3 are selected from the group consisting of ¨H and ¨000¨(R50)y¨R4, provided both R2 and R3 are ¨COO¨ (R50)y __ R4 when Ri is _______________________ H and provided only one of R2 or R3 is COO (R50)y R4 when Ri is ¨000¨(R50)y¨R4; R4 is ¨H or a Ci-C6 alkyl group; R5 is a Ci-C6 alkylene group; and y is 0 to 5; (b) propping open the high permeability zone; (c) pumping a second fluid into the formation; (d) dissolving the diverter particulates blocking the high permeability zone; and (e) producing hydrocarbons.
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
C09K 8/80 - Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
A rotary drilling apparatus for drilling deviated wellbores Is disclosed that in one embodiment includes a drilling assembly that further includes a drilling motor coupled to a drive member to rotate a disintegrating device, a housing outside the drive member having a lower section and an upper section, and a steering device disposed outside the drive member that tilts the lower section relative to the upper section and maintains the tilt geostationary or substantially geostationary when the drilling assembly is rotating to drill a deviated section of the wellbore.
A drilling assembly for use in drilling a wellbore is disclosed that in one embodiment includes a steering unit that includes a tilt device in a disintegrating device and an electro-mechanical actuation device having a force application member that applies axial force on the disintegrating device to tilt the disintegrating device about the tilt device along a selected direction. In one embodiment, the actuation device translates a rotary motion into an axial movement of the force application member to apply the axial force on the disintegrating device to tilt the disintegrating device about the tilt device.
A degradable polymer composite comprises: a polyurethane comprising one or more of the following groups: ester groups; carbonate groups; or ether groups, in a backbone of the polyurethane; and 1 to 30 parts by weight of either i) an acidic powder comprising sulfamic acid particles having an average size of 5 microns to 1 millimeter per 100 parts of the polyurethane, where the composite degrades into pieces having a largest dimension of less than two centimeters in 2 days to 2 weeks at a temperature greater than 100 F and lower than 200 F in water; or ii) a basic powder comprising particles having an average size of 5 microns to 1 millimeter per 100 parts of the polyurethane, wherein the basic powder comprises dissolvable glass powder, the dissolvable glass powder being a dissolvable silicate.
A drilling assembly for drilling deviated wellbores is disclosed that in one embodiment includes a steering unit having an upper section coupled to a lower section through a tilt device, wherein an electro-mechanical actuation device tilts the tilt device about a selected location in the drilling assembly to cause the lower section to tilt relative to the upper section along a selected direction while the drill string is rotating.
The flow control device comprises one or more stacked spiral paths where the shape of an inlet to an end of a spiral has a taper on one or more sides to gradually increase the polymer velocity to eliminate rapid acceleration points as the flow enters the spiral path. The entrance with its taper can be curved to get into the spiral. The spiral can be entered tangentially or radially or axially.
A method for providing well safety control in a remedial electronic submersible pump (ESP) application including a making up an electric submersible pump (ESP) on a conduit with a primary well control capability; running the foregoing through a preexisting SCSSV.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
A debris removal tool for removal of metallic debris from within a wellbore. The debris removal tool includes a housing defining a central bore and a plurality of magnetic members retained within the central bore and axially moveable therewithin, the magnetic members each presenting a contact surface to contact and form a magnetic attachment to the metallic debris.
A method of installing a downhole device comprises introducing a downhole device into a wellbore, the downhole device comprising a substrate and a shape memory polymer in a deformed state disposed on the substrate; combining a modified activation material in the form of a powder, a hydrogel, an xerogel, or a combination comprising at least one of the foregoing with a carrier to provide an activation fluid; introducing the activation fluid into the wellbore; releasing an activation agent in a liquid form from the modified activation material; and contacting the shape memory polymer in the deformed state with the released activation agent in an amount effective to deploy the shape memory polymer.
An modular apparatus for generating electrical power in a borehole penetrating the earth includes a body comprising first and second mechanical connectors at opposing ends and first and second electrical connectors at the opposing ends, the mechanical connectors and the electrical connectors being configured to connect with the same type of corresponding connectors on another modular apparatus when the modular apparatus and the another modular apparatus are stacked together. The modular apparatus further includes: an electrical generator having a rotor and stator in mechanical communication with the first and second mechanical connectors and in electrical communication with the first and second electrical connectors; and a turbine wheel coupled to or integrated with the rotor and comprising one or more turbine blades that are configured to interact with fluid flowing through the borehole causing the turbine wheel to rotate and the rotor to rotate in order to generate the electrical power.
An injection system comprises a fluid control member and a reciprocating member; wherein the fluid control member is configured to form a carbon composite-to-metal seal with the reciprocating member in response to application of a compressive force; the carbon composite comprising carbon and a binder containing one or more of the following: SiO2; Si; B; B2O3; a filler metal; or an alloy of the filler metal, and the filler metal comprising one or more of the following: aluminum; copper; titanium; nickel; tungsten; chromium; iron; manganese; zirconium; hafnium; vanadium; niobium; molybdenum; tin; bismuth; antimony; lead; cadmium; or selenium.
A borehole mill has blades that extend radially while moving along an inclined dovetail as a result of setting down weight on a mandrel. The blades extend axially beyond the end of the mandrel so that setting down weight disables a retainer that has the blades retracted for running in. Axial displacement of the blades along respective dovetails breaks a shear pin on a follower sleeve that is spring biased off a gage ring on the mandrel such that the spring stays compressed as long as set down weight is applied and once the mill is picked up the spring pushes the blades axially along a dovetail to the radially retracted position. The mill resumes its smallest dimension for pulling out of the hole.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
97.
CHEMICAL PROCESS FOR SULFUR REDUCTION OF HYDROCARBONS
Treatment of hydrocarbon streams, and in one non-limiting embodiment refinery distillates, with high pH aqueous reducing agents, such as borohydride, results in reduction of the sulfur compounds such as disulfides, mercaptans and thioethers that are present to give easily removed sulfides. The treatment converts the original sulfur compounds into hydrogen sulfide or low molecular weight mercaptans that can be extracted from the distillate with caustic solutions, hydrogen sulfide or mercaptan scavengers, solid absorbents such as clay or activated carbon or liquid absorbents such as amine-aldehyde condensates and/or aqueous aldehydes.
A method of determining a condition within a wellbore. The method comprises introducing a tubular member in a wellbore extending through a subterranean formation, the tubular member comprising a downhole article including a deformable material disposed around a surface of the tubular member, electrically conductive elements dispersed within the deformable material. The method includes measuring at least one electrical property of the deformable material. At least one of water ingress into the wellbore or an amount of expansion of the deformable material is determined based on the at least one measured electrical property. Related downhole systems and other related methods are also disclosed.
G01V 3/26 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
99.
SELF-LOCKING SLURRY TUBE CONNECTOR AND PROTECTION ARRANGEMENT
A Self-Locking Slurry Tube Connector and Protection Arrangement includes a jumper tube; a tube cover supporting and protective of the jumper tube. A connector sealed to the jumper tube and configured to move on the jumper tube from a first position to a second automatically locked position. A method for joining slurry tubes between adjacent sand screens.
An in situ method to deploy and/or plasticize a shape-memory material in order to change the material's physical dimensions and/or mechanical properties, includes a method for deploying a shape memory polymer having a deformed or compressed shape in an environment at a first temperature, the shape memory polymer having a first glass transition temperature which is greater than the first temperature. The method also includes contacting the shape memory polymer with an activation fluid in an amount effective to decrease the glass transition temperature of the shape memory polymer from the first glass transition temperature to a second glass transition temperature which is less than or equal to the first temperature, where the activation fluid comprises a sugar present in an amount effective to raise a flash point of the activation fluid.
patents
