Methods and apparatus for interrogating sets of optical elements having characteristic wavelengths spanning a sweep range while avoiding overlapping reflections from the different sets when performing a wavelength sweep are provided. One example method generally includes introducing a pulse of light, by an optical source, into an optical waveguide to interrogate at least first and second sets of optical elements, wherein the optical elements within each set have different characteristic wavelengths and wherein the first and second sets are separated in time such that a first time window over which light is reflected from the optical elements in the first set and reaches a receiver does not overlap with a second time window over which light is reflected from the optical elements in the second set and reaches the receiver; and processing the reflected light to determine one or more parameters corresponding to the optical elements.
G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
A method for using a Focused Ion Beam and/or Scanning Electron Microscope (FIB/SEM) for etching one or more alignment markers (210, 230) on a rock sample (200), the one or more alignment markers (210, 230) being etched on the rock sample (200) using the FIB/SEM. The one or more alignment markers (210, 230) may further be filled with a platinum alloy or other suitable compositions for increasing alignment marker contrast.
G01N 23/225 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material using electron or ion microprobes
A method and apparatus for steering a drilling assembly (200) during drilling operations for oil and gas. The steering assembly being disposed in a borehole (10) and comprising a drill bit (120) attached to a drill collar (210) having an eccentric stabilizer (220) disposed thereupon. The eccentric stabilizer either in an engaged state whereupon rotating concentrically with the drill collar, or in a released state whereupon as the drill collar rotates the eccentric stabilizer is positioned eccentrically relative to the drill collar creating a lateral deflection in the borehole that may be used for changing the direction of the drilling assembly.
An apparatus deploys on a casing and has a toe with first and second ports for communicating with a wellbore. A packing element between the ports is actuatable to isolate portions of the wellbore. The toe operates in a first condition for run-in to prevent fluid communication through the ports, although washdown can flow through a toe port. Once installed, the toe operates in a second condition for cementation when the first plug is deployed to the toe. In this condition, the toe actuates the packing element, permits fluid communication through the first port, and prevents fluid communication through the second port. After cementation, the toe operates in a third condition for fracture and completion operations when the second plug is deployed. The toe in this condition prevents fluid communication through the first port, but permits fluid communication through the second port downhole of the set packing element.
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
A composite mandrel has structural support in the inner bore. This can be accomplished in a couple of different ways. One option is to insert the composite mandrel support into the inner bore of a completed mandrel and to secure the insert into place with pins, adhesive, etc. Another option is to have a cross-beam or I-beam supported structural insert that is wound over with a filament wound composite process. Using this option, the inner bore support remains in place once manufacturing is complete and allow flows back from downhole of the bridge plug. When used, the structural support allows for higher collapse ratings [i.e., higher frac pressures or higher temperature ratings] on the composite mandrel. Providing a filament winding over the structural support also eliminates the need to use a conventional metal rod for winding on to produce the mandrel and then pulled out to leave the inner bore of the mandrel, thus also making the manufacturing process more efficient.
Plugs (50) for deployment downhole include a body (52) composed of a first material and include an activating element (60) disposed internally in the body. The activating element has an agent (62) configured to degrade the body. However, the agent is kept from degrading the body until occurrence of an activating trigger. The activating element can include a shell (64) enclosing the agent therein and keeping the agent from reacting with the body's material. The shell can be composed of a breachable material that is breached to allow the agent to react with the first material. To breach the shell, the activating element can further include a breaching element that breaches the shell in response to the activating trigger.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
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
Re-treatment of a formation having a wellbore, which can be an open hole or a cased hole lined with casing, involves deploying a tubing string in the casing having tools disposed at intervals thereon. The tools position on the tubing string, and the tubing string with the tools thereon is inserted into the casing. Biasing rings of the tools passively engage with the casing. The annulus is accessed between the tubing string and the casing at the intervals between the tools. For example, sliding sleeves on the tubing string can be opened (selectively), or new plug and perforation operations can be used to create perforations in the tubing string at desired intervals between the tools. With access achieved, retreatment is pumped down the tubing string, out the access to the annulus, and at least partially sealed by the engaged rings in the intervals between the tools.
A pressure relief valve assembly may be coupled to one or more casings and/or tubular members to control fluid communication therebetween. In one embodiment, the valve assembly includes a tubular body having a port for fluid communication between an exterior of the tubular body and an interior of the tubular body; a chamber formed in a wall of the tubular body, the chamber in fluid communication with the port; a closure member disposed in the chamber and configured to control fluid communication through the port in response to a pressure differential; and a retaining member coupled to the closure member for retaining the closure member in an open position.
A gravel pack assembly includes screen sections with a packer between them. A first screen section communicates an uphole annulus with the assembly's interior passage, and a second screen section communicates a downhole annulus with the interior passage. A housing of the packer has an internal bore communicating with the assembly's interior passage and has an internal bypass communicating external ports with one another. A first packer element disposed between the external ports restricts gravel passage at least from the uphole to the downhole annulus. A second packer element disposed downhole from a second of the external ports is independently actuated to isolate fluid passage between the uphole and downhole annulus. One or more transport tubes communicate slurry from the uphole annulus to the internal bypass once the uphole annulus is packed with gravel.
A packer has a swellable element and has end rings and compressible elements at each end of the swellable element. The packer may be first set using internal bore pressure to compress one of the compressible elements against one of the end rings with a first hydraulic setting mechanism. The packer may then be set a second time using annulus pressure to compress against the other compressible element with a second hydraulic setting mechanism. Either way, the compressible elements are compressed to expand out to the borehole and to limit extrusion of the swellable element outside the compressed elements.
Real-time or near real-time estimates of reservoir quality properties, along with performance indicators for such estimates, can be provided through use of methods and systems for fully automating the estimation of reservoir quality properties based on geochemical data obtained at a well site.
G06F 7/60 - Methods or arrangements for performing computations using a digital non-denominational number representation, i.e. number representation without radixComputing devices using combinations of denominational and non-denominational quantity representations
An isolation valve for use in a wellbore includes: a tubular housing; an upper flapper disposed in the housing and pivotable relative thereto between an open position and a closed position; an upper piston operable to open or close the upper flapper; a lower flapper disposed in the housing and pivotable relative thereto between an open position and a closed position; a lower piston operable to open the lower flapper; an opener passage in fluid communication with the pistons and an opener hydraulic coupling; and a closer passage in fluid communication with the pistons and a closer hydraulic coupling.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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
13.
METHOD AND SYSTEM FOR TRACKING MOVEMENT TRAJECTORY OF A PIPELINE TOOL
The invention relates to systems for inspection of mainline and flowline oil pipelines, gas pipelines and oil product pipelines and may be used for tracking in-line diagnostic tools passing inside the inspected pipelines and for determining of locations of pipeline features. The technical result consists in an improved accuracy of determining the time when the pipeline tool passes near the reference points and thus accuracy of determining the location of pipeline features. This result is achieved by passing the tool inside the pipeline, measuring physical quantities characterizing the status and/or characteristics of the tool and/or of the pipeline by a measurement system, and recording them in a tool data storage such that they are associated with time determined by a tool clock. A logger installed near a reference point in the pipeline is used to measure physical quantities that allow to identify the passing of the tool near the logger, characteristics that identify the respective time instants of the passing of the tool according to the logger clock are generated and recorded onto the logger data storage. A transmitter arranged in one of the tool and the logger is used to transmit a signal having a temporal characteristic associated with the clock time on the transmitter side; the transmitted signal is received by a receiver arranged in the other one of the logger and the tool, and a characteristic related to the temporal characteristic of the received signal is recorded onto the data storage on the receiver side such that it is associated to the clock time on the receiver side. A difference between the clock times on the transmitter side on the receiver side is determined, and hence a value of time difference according to the logger clock and the tool clock, and is used in the reference point to determine the characteristics of the pipeline.
G01C 7/06 - Tracing profiles of cavities, e.g. tunnels
G01C 21/16 - NavigationNavigational instruments not provided for in groups by using measurement of speed or acceleration executed aboard the object being navigatedDead reckoning by integrating acceleration or speed, i.e. inertial navigation
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
F16L 55/48 - Indicating the position of the pig or mole in the pipe or conduit
G06F 17/30 - Information retrieval; Database structures therefor
H04L 27/10 - Frequency-modulated carrier systems, i.e. using frequency-shift keying
A container for collecting water samples to determine dissolved gas includes a flask-type pouch with a spout. A removable cap and valve install on the spout. The valve includes an adapter that fits with an O-ring or other seal inside the mouth of the spout. The valve includes a valve element, which can be a one-way, self-closing type of valve, that fits with an O-ring or other seal inside the end of the adapter. A cap of the container fits over the adapter and affixes to the spout to hold the valve on the spout. In use, the cap can be removed so that the valve element and adapter can be removed for filling the pouch. Otherwise, the cap can remain in place so filling can be performed through the valve element. A tamper-evident ring on the cap may be provided to ensure the integrity of the sample contained in the flask.
A holding device having release mechanisms for securing and releasing one or more ball, dart, and/or plug members from the holding device into a tubular string disposed in a wellbore. The release mechanisms may include a planetary gear arrangement for extending and retracting a plunger member disposed below the ball, dart, and/or plug members. The release mechanisms may include a bevel gear arrangement for extending and retracting a finger support member disposed below the ball, dart, and/or plug members. The release mechanisms may include a pivotable, spring type arrangement for extending and retracting a finger support member disposed below the ball, dart, and/or plug members.
A downhole tool has a housing, a mandrel, a seat, and a piston. The housing defines a first bore, and the mandrel is movably disposed in the first bore and defines a second bore. The mandrel has first and second mandrel sections or upper and lower cones, and the first mandrel section defines a cross-port communicating the second bore with an annular space between the mandrel and the housing. The seat is disposed in the first bore of the housing between the first and second mandrel sections. The seat is movable to a constricted state in the first bore to catch a dropped ball and is movable to an expanded state in the first bore to pass a dropped ball. The piston is disposed in the annular space and at least temporality supports the seat in its constricted state.
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
A device and method prevent damage to an anti-extrusion device on a tool, such as a plug or a packer, prior to and during setting of the tool. Typically, the upper or outer edges of the anti-extrusion device are relatively delicate. A reinforcing band on the device's sheath strengthens or armors the upper or outer edge of the anti-extrusion device so the anti-extrusion device may be protected while running the tool into the well or casing. Longitudinal slots on the sheath allow the sheath to expand at least partially with the expansion of the sealing element, while the reinforcing band resists expansion of the distal edge of the sheath.
The present invention generally relates to a weight setting indicator which is used to indicate that an applied force to a tool achieved or exceeded a predetermined amount. In one asepct, a packer actuator (100) for use with a packer is provided. The packer actuator includes a body (105) with a recess (135). The packer actuator further includes a dog assembly (175) disposed in the recess (135) of the body (105). The dog assembly (175) is configured to set the packer when a force is applied to the packer actuator (100). The packer actuator (100) also includes a setting indicator (200) disposed in the recess adjacent an end of the dog assembly (175). The setting indicator (200) is configured to move from a pre-set position to a post-set position when the force is applied to the packer actuator, wherein the setting indicator (200) is plastically deformed in the post-set position.
A downhole tool has a housing, mandrel, and ball seat. The housing defines a first bore, and the mandrel defines a second bore. The mandrel is disposed in the first bore of the housing and defines an annular space with the housing. The ball seat is rotatably disposed in the second bore of the mandrel and defines an interior passage with a seat profile. First and second pistons are disposed in the annular space on opposing sides of the ball seat. These first and second pistons are movable along an axis of the tool in the annular space in opposing directions and are adapted to rotate the ball seat. Additionally, first and second biasing members are disposed in the annular space and bias the first and second pistons toward one another to reset the ball seat in the absence of pressure.
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
A device and method allow a longer sealing element to be used on a packer or other downhole tool while providing an increase in the total amount of setting force that can be used and providing for more uniform or balanced setting of the sealing element. The packer may be first set using internal bore pressure to radially expand one end of the sealing element with a first hydraulic setting mechanism. The packer may then be set a second time using annulus pressure to continue the radial expansion of the sealing element with a second hydraulic setting mechanism.
A rotatable mandrel for use in a filament winding process to form a composite material includes a body having at least one peak and at least one valley on an external surface of the body. The mandrel is rotatable and is configured to receive fibers on the at least one peak and the at least one valley.
B29C 70/32 - Shaping by lay-up, i.e. applying fibres, tape or broadsheet on a mould, former or coreShaping by spray-up, i.e. spraying of fibres on a mould, former or core on a rotating mould, former or core
22.
REAL-TIME DETERMINATION OF FORMATION FLUID PROPERTIES USING DENSITY ANALYSIS
Analysis evaluates formation fluid with a downhole tool disposed in a borehole. A plurality of possible constituents is defined for the formation fluid, and constraints are defined for the possible constituents. The constraints can include boundary constraints and constraints on the system's dynamics. The formation fluid is obtained from the borehole with the downhole tool over a plurality of time intervals, and density of the obtained formation fluid is obtained at the time intervals. To evaluate the fluid composition, a state probability distribution of the possible constituents of the obtained formation fluid at the current time interval is computed recursively from that at the previous time interval and by assimilation the current measured density of the obtained formation fluid in addition to the defined boundary/dynamic constraints. The probabilistic characterization of the state of the possible constituents allows, in turn, the probabilistic inference of formation properties such as contamination level and GOR.
A downhole tool for use in a wellbore having a tool body with a blade assembly slidably mounted thereon and movable between a retracted and an outwardly extended position. The blade assembly is biased towards the retracted position and movable with an actuating force to the extended position. The tool includes an indexer constructed and arranged to facilitate movement of the blade assembly.
An expandable tubular system that includes a launcher section coupled to a tubular string and that houses an expansion device (230). A shoulder section that is formed at a transition point between the launcher section and the tubular string has a wall thickness (240) greater than the wall thicknesses of the tubular string (210) and the launcher section (220). The shoulder section has an inner diameter less than inner diameters of the launcher section and the tubular string. The shoulder section is arranged to increase the force required to begin expansion of the tubular string and increase the contact area between the inner surface of the shoulder section the expansion device when supporting the weight of the tubular string.
An expandable tubular for use in a wellbore includes: a pin formed at a first longitudinal end of the expandable tubular; a box formed at a second longitudinal end of the expandable tubular; a tubular body connecting the pin and the box; and an elastomeric seal disposed in a groove of the box. Each of the pin and box has: a torque shoulder; and a thread. The pin has an asymmetric protrusion formed on an inner surface thereof.
A slip assembly for a downhole tool, such as a bridge plug, has a slip body composed of independent segments. The segments are affixed together along their longitudinal sides by a bond, which can be composed of thermoplastic or thermoset resins, an elastomer, epoxy adhesives, bonding agent manufactured using ceramic, metallic agent, or a combination of these. The surface area over which the bonding agent is applied can be controlled for a particular implementation. Thus, more or less of the longitudinal sides of the segments can be bonded to other segments. This provides greater control of the required force to break the bond itself, which can be tailored as desired.
The present invention generally relates to a deepset wireline retrievable safety valve for controlling fluid flow through a production tubing string. In one aspect, a valve for use in a wellbore is provided. The valve includes a housing having a bore. The valve further includes an actuator sleeve movable within the housing between a retracted position and an extended position. The actuator sleeve in the retracted position allows a flapper member to obstruct the bore in the housing. Additionally, the valve includes a first piston member attached to a first side of the actuator sleeve and a second piston member attached to a second side of the actuator sleeve, wherein wellbore fluid pressure acts on the first piston member, which results in a first force, and acts on the second piston, which results in a second force, and the first force and the second force are applied to the actuator sleeve in an opposite direction.
A controller for operating a downhole tool includes a tubular body; a seat disposed in the body for receiving first and second pump-down plugs, at least a portion of one of the seat and the plugs being radially displaceable to pass through or allow passage of the other at a first threshold pressure differential; a catcher located below the seat for receiving the plugs after passing through the seat; a toggle linked to the seat to alternate between a locked position and an unlocked position in response to seating of the plugs; and a control mandrel for engaging a piston of the downhole tool and linked to the toggle: to be longitudinally movable between a first position and a second position when the toggle is unlocked, and to be prevented from movement from the first position to the second position when the toggle is locked.
A downhole tool (250) with a swellable mantle (200) is configured for insertion of a cable (140) into a longitudinal slit (210) in the mantle. An arcuate groove (240) is formed in an outer surface of the mantle corresponding to a displacement caused by the inserted cable, so that the displacement is counteracted and the outer surface of the mantle remains smooth.
A slurry mixing system calculates a density of a slurry using measured pressure differential and bulk velocity of the slurry. Slurry from mixing of dry blend and mix fluid enters a one or more tanks having agitators. A pump then pumps the slurry from the tank(s) to the well, and a portion of the slurry is recirculating back to a mixer. From the recirculated path, a direct slurry weight sensor measures a pressure differential of the slurry between two vertical measurement points of a known volume, and the sensor measures a velocity of the recirculated slurry. Based on these measures, the controller calculates a density of the slurry, monitors a ratio of the dry blend and the mix fluid, and adjusts the ratio based on the calculated density of the slurry if there is a discrepancy.
In one embodiment, a tubular handling assembly for use with a top drive includes a mandrel (110) coupled to the top drive; a gripping assembly (100) for gripping and releasing a tubular, the gripping assembly coupled to and rotating with the mandrel; and an actuation assembly (136) for actuating the gripping assembly, wherein the gripping assembly is rotatable relative to the actuation assembly.
A sliding sleeve has an inner sleeve that moves in a housing. For example, the inner sleeve can move open relative to a port in the housing when a deployed ball engages a seat in the inner sleeve. Because the seat and the ball (if remaining) are preferably milled out of the inner sleeve after use, the inner sleeve preferably does not rotate in the housing during milling operations. To accomplish this, an anti-rotation clutch assembly in the sliding sleeve helps prevent the inner sleeve from rotating. A wedged cone is formed on a distal end of the inner sleeve and press fits into a cupped shoulder on the inside of the sleeve's housing.
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
A packer or plug for use in a wellbore includes: a tubular mandrel (27) made from a composite material including a pyrotechnic composition; an expandable seal (30) disposed on an outer surface of the mandrel; and an igniter (31) operable to initiate combustion of the mandrel.
E21B 29/02 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground by explosives or by thermal or chemical means
A device and method to control the rate of radial expansion of a compressible sealing element on a packer over the longitudinal length of the sealing element. By varying the rate of compression of the element, the rate of radial expansion of the corresponding portions of the element may also be controlled. Additionally, the rate of radial expansion may also be controlled by controlling the direction and amount of radial expansion along the length of the sealing by reinforcing certain portions of the sealing element while decreasing the rigidity of the reinforcement for other portions.
A ball is used for engaging in a downhole seat and can be milled out after use. The ball has a spherical body with an outer surface. An interior of the spherical body is composed of a metallic material, such as aluminum. The spherical body has a plurality of holes formed therein. The holes extend from at least one common vertex point on the outer surface of the spherical body and extend at angles partially into the interior of the spherical body.
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
The present invention generally relates to a hydraulic communication device (10)that is used in a wellbore for fluid communication during a wellbore operation. In one aspect, a hydraulic communication device (10) is provided. The hydraulic communication device includes a body (30) having a central passageway (40) and a bore (55) formed in a wall of the body. The bore is in fluid communication with the central passageway, and the bore is configured to receive an end of a control line (25). The hydraulic communication device further includes a plug assembly (100) disposed in the bore formed in the wall of the body. The plug assembly is movable from a first position in which fluid communication through the bore is blocked and a second position in which fluid communication through the bore is unblocked.
A method of manufacturing or surface treating a wire wrapped screen for use in a wellbore improves the erosion resistance of the wire-wrapped screen. The wire-wrapped screen can be disposed on an axle positioned in a chamber containing a source of erosion resistant surface coating. The coating is then deposited on the exterior of the wire-wrapped screen using a deposition process, such as physical vapor deposition or thermal spraying. Alternatively, a spray system proximate the wire-wrapped screen can have a deposition nozzle to coat the exterior surface of the screen with an elastomer coating by spraying an elastomer. In additional embodiments, the wire for the wire-wrapped screen can first be treated for erosion resistance and then wound about a mandrel to form the wire-wrapped screen.
A sliding sleeve (100) opens with a deployed ball (B). The sleeve has a seat (190) disposed in the housing, and the seat disposed inan inner sleeve (130) has a - conical shape with a top open end and a base open end. The seat (194) has an initial state with the top open end disposed more toward the proximal end of the inner sleeve than the bottom open end. In this initial state, the seat engages the deployed ball with a first contact area and moves the inner sleeve open in response to first fluid pressure applied against the deployed ball in the seat. As this occurs, the seat deforms at least partially from the initial state to an inverted state in the opened inner sleeve in response to second fluid pressure applied against the deployed ball. In this inverted state, the seat engages the deployed ball with a second contact area greater than the first contact area.
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 43/26 - Methods for stimulating production by forming crevices or fractures
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
39.
SLIDING SLEEVE HAVING CONTRACTING, RINGED BALL SEAT
A sliding sleeve opens with a deployed ball, the sleeve comprising: a housing (120) defining a first bore and defining a flow port (127) communicating the first bore outside the housing; an inner sleeve (130) defining a second bore and being movable axially inside the first bore from a closed position to an opened position relative to the flow port, the second bore having a transition shoulder (185) and an engagement shoulder (187) disposed therein; and a compressible seat (182) disposed in a first axial position in the second bore of the inner sleeve, the compressible seat in the first axial position having an expanded state and engaging the deployed plug (B), the compressible seat moving the inner sleeve axially open in response to fluid pressure applied against the engaged plug, the compressible seat shifting from the first axial position past the transition shoulder to a second axial position and contracting from the expanded state to a contracted state in response to the applied fluid pressure, the compressible seat transitioned to the contracted state compressing against the engaged plug.
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 43/26 - Methods for stimulating production by forming crevices or fractures
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
40.
SLIDING SLEEVE HAVING CONTRACTING, SEGMENTED BALL SEAT
A sliding sleeve (100) opens with a deployed ball (B). The sleeve has a seat (150) disposed in the housing (120), and the seat has segments (152) biased outward from one another with a C-ring or other biasing element (154). Initially, the seat has an expanded state in the sliding sleeve so that the seats segments expand outward against the housing's bore. When an appropriately sized ball is deployed downhole, the ball engages the expanded seat. Fluid pressure applied against the seated ball moves the seat into the inner sleeve's bore. As this occurs, the seat contracts, which increases the engagement area of the seat with the ball. Eventually, the seat reaches the shoulder (137) in the inner sleeve so that pressure applied against the seated ball now moves the inner sleeve in the housing to open the sliding sleeve's flow port (126).
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 43/26 - Methods for stimulating production by forming crevices or fractures
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
41.
SLIDING SLEEVE HAVING RAMPED, CONTRACTING, SEGMENTED BALL SEAT
A sliding sleeve (100) opens with a deployed ball (B). The sleeve comprising:a housing (1210) defining a first bore and defining a flow port (127) communicating the first bore outside the housing; an inner sleeve (130) defining a second bore and being movable from a closed position to an opened position inside the first bore relative to the flow port; an inner-facing surface (169) disposed in the second bore and inclined from a proximal end toward a distal end of the inner sleeve; and a seat (160) disposed in the second bore of the inner sleeve and being movable axially from a first axial position toward a second axial position therein, the seat having a plurality of segments (164) having inclined surfaces adapted to engage the inner-facing surface, the segments on the seat in the first axial position being expanded outward from one another and engaging the deployed plug, the segments on the seat moved toward the second axial position being contracted inward by engagement of the inclined surfaces with the inner-facing surface and wedging against the engaged plug, the seat moving the inner sleeve axially to the opened position in response to fluid pressure applied against the engaged plug.
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 43/26 - Methods for stimulating production by forming crevices or fractures
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
42.
SLIDING SLEEVE HAVING CONTRACTING, DUAL SEGMENTED BALL SEAT
A sliding sleeve (100) opens with a deployed ball (B). The sleeve has a seat (170) disposed in a bore of the inner sleeve and comprises a landing ring (172) disposed in the bore and being movable axially from a first axial position to a second axial position therein. A compressible ring (174) is also disposed in the bore and defines a space between a portion of the compressible ring and the bore. The landing ring in the first position supports the deployed ball with a first contact dimension and moves the inner sleeve to the opened position in response to application of first fluid pressure against the engaged ball. The landing ring moves from the first position to the second position in the inner sleeve when in the opened position in response to second fluid pressure applied against the engaged ball. The landing ring in the second position fits in the space between the compressible ring and the second bore and contracts the compressible ring inward. As a result, the segments moved inward support the engaged ball with a second contact dimension narrower than the first contact dimension.
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 43/26 - Methods for stimulating production by forming crevices or fractures
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 sliding sleeve (100) opens with a deployed ball (B). The sleeve comprising: a housing (120) defining a first bore and defining a flow port communicating the first bore outside the housing; an inner sleeve(130) defining a second bore and being movable axially from a closed position to an opened position inside the first bore relative to the flow port, the second bore having a shoulder (206) disposed therein;and a movable ring (202) is disposed in a bore of an inner sleeve adjacent the shoulder. The movable ring engages a deployed ball with a first contact area and moves the inner sleeve open with the deployed ball. A deformable ring (204), which can be composed of an elastomer or the like, is also disposed in the inner sleeve's bore between the shoulder and the movable ring. With the application of increased pressure, the movable ring moves in the inner sleeve with the deployed ball toward the shoulder, and the deformable ring deforms in response to the movement of the movable ring toward the shoulder. As a result, the deformable ring engages the deployed ball when deformed and increases the engagement with the deployed ball to a second contact area greater than the first contact area.
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 43/26 - Methods for stimulating production by forming crevices or fractures
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 multi-zone formation treatment assembly has sections disposed on a tubular structure in a borehole. An isolation element disposed on the tubular structure that isolates a borehole annulus around the section from the other sections, and a flow valve disposed on the tubular structure is selectively operable between opened and closed conditions permitting and preventing fluid communication between the through-bore and the borehole annulus. A screen disposed on the tubular structure communicates with the borehole annulus, and a closure disposed on the tubular structure at least prevents fluid communication from the through-bore to the screen. A workstring of the assembly can be manipulated in the tubular structure relative to each section in the same trip to: open the flow valve, position in the through-bore relative to the open flow valve, deliver the treatment from an outlet to the section through the open flow valve, and close the flow valve.
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
A device and method to allow a sucker rod to be disconnected at a particular point in a sucker rod string (20). Typically the disconnect device (100) is located just above the barrel pump (32) where the disconnect device is able to provide tensile and compressive strength similar to the sucker rod string thereby eliminating at least one failure mode for the sucker rod string.
Swellable compositions including at least one curable elastomer, a least one cure system, at least one high molecular weight (HMW) swelling agent and at least one low molecular weight (LMW) swelling agent. Methods for making swellable compositions including at least one curable elastomer, a least one cure system, at least one high molecular weight (HMW) swelling agent and at least one low molecular weight (LMW) swelling agent. Methods for using swellable compositions including at least one curable elastomer, a least one cure system, at least one high molecular weight (HMW) swelling agent and at least one low molecular weight (LMW) swelling agent.
C08L 101/14 - Compositions of unspecified macromolecular compounds characterised by physical features, e.g. anisotropy, viscosity or electrical conductivity the macromolecular compounds being water soluble or water swellable, e.g. aqueous gels
A method and apparatus for circulating fluid in a wellbore includes a bottom sub 130 having a bottom sub port and a mandrel 35, wherein the mandrel 35 substantially forms an inner bore of the circulating tool and includes a mandrel port. The circulating tool may also include an activation piston 46 that is movable in a first direction and a port piston 64 movable in a second direction when the activation piston 46 moves in the first direction. The circulating tool may further include an inner sleeve 90 coupled to the port piston 64 and movable with the port piston, the inner sleeve 90 having an inner sleeve port in selective communication with the mandrel port. When the inner sleeve port is in communication with the mandrel port at least partially, circulating fluid is allowed to flow through the bottom sub port to the wellbore.
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
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
A tachometer for a downhole motor includes: a tubular housing having a coupling for connection to a housing of the motor; and a probe. The probe: has a coupling for connection to a rotor of the motor, is movable relative to the tachometer housing, and has at least a portion disposed in a bore of the tachometer housing. The tachometer further includes electronics disposed in the tachometer housing and including: a battery; one or more proximity sensors for tracking an orbit of the probe; and a programmable logic controller (PLC). The PLC is operable: to receive the tracked orbit, and at least one of: to determine an angular speed of the probe using the tracked orbit, and to forecast a remaining lifespan of the motor using the tracked orbit.
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 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
49.
MEASURING THE PROPERTIES AND AMOUNT OF PRODUCIBLE OIL IN SHALE-OIL RESERVOIR SAMPLES
The subject matter of the present disclosure is directed to developing a method of measuring the amount of producible oil and the producible oil saturation in shale-oil reservoirs using sample source rock. Further, the physical and chemical properties and amounts of producible oil in shale-oil reservoir samples may be determined. First and second solvents are applied to a sample source rock to extract petroleum from the sample source rock. The extracted source rock, the twice-extracted source rock, and the first and second extracted petroleum may be analyzed to determine the characteristics and properties of the reservoir rock.
In one embodiment, the sealing apparatus includes a mandrel having at least two portions, a first portion having a seal ring disposed on an exterior surface and a second portion without a seal ring disposed on an exterior surface. In one embodiment, the seal ring is disposed around the first portion. In another embodiment, the burst and collapse integrity of the first portion is substantially the same as the second portion.
A telemetry system and method configured to communicate a wellbore parameter such as fluid composition, temperature, and pressure. In one embodiment, a plurality of tracers is stored downhole, and each of the tracers represents a different value of the wellbore parameter. After measuring the wellbore parameter, the measured value is correlated to one or more of the plurality of tracers that is equivalent to the measured value of the downhole parameter. The one or more tracers representing the measured value are then released from their respective containers to travel upstream. A sensor located upstream may detect the one or more tracers, which are then correlated back to obtain the measured value of the wellbore parameter. In another embodiment, ratiometric amounts of the tracers may be used to represent additional values of the wellbore parameter.
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
52.
MANIPULATION OF MULTI-COMPONENT GEOPHONE ARRAY DATA TO IDENTIFY DOWNHOLE CONDITIONS
Methods and apparatus for using multi-component geophones and/or multi-component geophone arrays to measure flow-induced acoustic energy produced in wellbores are provided. With the use of the multi-component geophones, the measured acoustic energy may be resolved into its directional components. The computed directional energy components may be mathematically compared to numerically highlight ambient flow conditions (e.g., leaks in casing or other conduit, points of fluid entry/exit/restrictions between the casing and the formation). The use of an array of multi-component geophones allows for the use of geophone move-out curves to further identify acoustic energy source locations.
A method of analyzing a geologic sample by NMR is provided for detecting the presence of organic solid and semi-solid materials and saturating fluids by comparing the results of a baseline NMR pulse sequence test with the results of a magnetization transfer contrast NMR pulse sequence test wherein the magnetization transfer NMR test involves a first application of a magnetization transfer contrast preparation RF pulse sequence sufficient to decrease or destroy magnetization coherence attributable to any organic solid and semisolid materials that might be in the geologic sample followed by application of the baseline NMR pulse sequence.
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
An expandable tubular assembly includes an expander 190 for expanding a tubular 125. The expander 190 may be hydraulically actuated. A bore obstruction object 206 may be received in a receptacle sleeve 210 that is a modular component of the expandable tubular assembly. In this respect, the expandable tubular assembly may be quickly fitted with a receptacle sleeve 210 designed to receive selected type of bore obstruction object 206.
An optical transducer is provided. A "measuring" portion of the transducer may be exposed to a high pressure and fluids when the optical transducer is deployed (e.g., in a wellbore or other industrial setting). The transducer may include an optical waveguide with a first portion that forms a first seal that isolates an "instrumentation" portion of the transducer from exposure to the high pressure and fluids to which the measuring portion may be exposed. The transducer may also include a second seal with a "stack" of material elements that contact a second portion of the optical waveguide to also isolate the instrumentation portion of the transducer from exposure to the high pressure and fluids to which the measuring portion may be exposed.
G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
G02B 6/44 - Mechanical structures for providing tensile strength and external protection for fibres, e.g. optical transmission cables
G02B 6/42 - Coupling light guides with opto-electronic elements
56.
APPARATUS AND METHODS OF RUNNING AN EXPANDABLE LINER
An apparatus for carrying and releasing a liner (11) downhole includes a tubular body (15); a latching member (17) attached to the tubular body (15) for coupling with the liner (11); and a release sleeve (21) disposed between the tubular body (15) and the latching member (17), wherein the release sleeve (21) is axially movable relative to the tubular body (15) to allow the latching member (17) to disengage from the liner (11).
Methods and apparatus are provided for continuously powering tools downhole for extended periods of time, such as for the life of the producing well. Batteries may power the downhole tools, but traditionally, the batteries may last up to 2 years, and in some cases, up to 5 years may be reached with an optimized data sampling rate and power management scheme. After that time, operations may be halted temporarily for replacing the batteries. According to embodiments of the present invention, in contrast, rechargeable batteries 204 may be utilized downhole to provide power to operate the tools, and rather than halting operations and retrieving the rechargeable batteries 204 to the surface for recharging, reserve batteries 208/210 may be used for recharging the rechargeable batteries 204. In many cases, these well tools may be designed to operate for a long period of time (e.g., around 10-20 years), depending on the life of the producing well.
A releasable latch system used to releasably couple a surface casing to a conductor casing. In one embodiment, a latch assembly for coupling a first tubular to a second tubular includes a mandrel having a plurality of key slots; a housing for receiving the mandrel; a plurality of keys radially movable into engagement or out of engagement with a respective key slot; a collet configured to engage the housing and a respective key; and a retainer ring configured to hold the plurality of keys in engagement with the respective key slot.
E21B 17/046 - CouplingsJoints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
E21B 7/20 - Driving or forcing casings or pipes into boreholes, e.g. sinkingSimultaneously drilling and casing boreholes
In one embodiment, a casing bit drive assembly may be used with a casing drilling system. The casing bit drive assembly may include one or more of the following: a retrievable drilling motor; a decoupled casing sub; a releasable coupling between the motor and casing bit; a releasable coupling between the motor and casing; a cement diverter; and a casing bit.
Embodiments of the present disclosure generally provide a disc-valve design with a self-cleaning feature. The self-cleaning feature may be integrated into the valve, for example, by removing a "cut-out" portion between sealing surfaces of ports. These cut-out portions may create vortices that might clean debris from the sealing surfaces. The cut-outs may also provide a place for debris to collect-keeping it away from the sealing surfaces. In addition, or as an alternative to cut-outs, some other type of mechanism, such as sealing members designed to disturb flow to sweep away debris near a sealing surface or helical grooves (rifling) formed in the ports, may also be used to promote self-cleaning.
A method of drilling a subsea wellbore includes drilling the wellbore by injecting drilling fluid through a tubular string extending into the wellbore from an offshore drilling unit (ODU) and rotating a drill bit disposed on a bottom of the tubular string. The method further includes, while drilling the wellbore: mixing lifting fluid with drilling returns at a flow rate proportionate to a flow rate of the drilling fluid, thereby forming a return mixture. The lifting fluid has a density substantially less than a density of the drilling fluid. The return mixture has a density substantially less than the drilling fluid density. The method further includes, while drilling the wellbore: measuring a flow rate of the returns or the return mixture; and comparing the measured flow rate to the drilling fluid flow rate to ensure control of a formation being drilled.
A downhole assembly, such as a toe-to-heel gravel pack assembly, has a body with a body passage, outlet ports for slurry, and screens for fluid returns. An inner string deploys in the body to perform the toe-to-heel gravel packing. A telescoping adjustment device (30) allows the inner string to space out properly when deployed to the toe of the assembly. The adjustement device (30) comprises a first member (60) coupled to one portion of the inner string;a second member (40) telescopically coupled to the first member and coupled to another portion of the inner string; at least one ratchet (65) disposed on the first member (col. 4, lines 22-28); and at least one catch (50) disposed on the second member and movable relative to the at least one ratchet. Sealing surfaces or seats of a locating device in the body separate a sealable space and seal against seals on the inner string movably disposed therein. Fluid pumped in the string produces a pressure buildup when the string's port communicates with the sealable space. The pressure buildup indicates that the tool is positioned at a first location in the assembly, and other positions for placement of the tool can then be calculated therefrom.
A downhole assembly, such as a toe-to-heel gravel pack assembly, has a body with a body passage, outlet ports for slurry, and screens for fluid returns. An inner string deploys in the body to perform the toe-to-heel gravel packing. A telescoping adjustment device allows the inner string to space out properly when deployed to the toe of the assembly. Sealing surfaces of a locating device in the body separate a sealable space and seal against seals on the inner string movably disposed therein. Fluid pumped in the string produces a pressure buildup when the string's port communicates with the sealable space. The pressure buildup indicates that the tool is positioned at a first location in the assembly, and other positions for placement of the tool can then be calculated therefrom.
A gravel packing assembly gravel packs a horizontal borehole (10). Operators wash down the borehole using an inner string (110) in a first position by flowing fluid from the inner string (110) through the apparatus' toe. Operators then gravel pack by moving the inner string (110) to one or more flow ports (132, 132A, 132B) between a screen (140) and the toe. Slurry flows into the borehole from the flow ports (132, 132A, 132B), and returns from the borehole flow through the screen (140). The gravel in the slurry can pack the borehole in an alpha-beta wave from toe to heel. In another condition, operators can move the inner string to a second flow port so slurry can flow into the borehole through a shunt extending from the second flow port. When gravel packing is done, operators move the inner string (110) to a port collar (160B) in a liner (170) of the assembly to cement the liner (170) in the borehole (10).
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
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
A gravel pack operation disposes slurry from an inner string into the annulus around a shoe track. A valve on the shoe track can open and close flow through a port, and seats around the port allow an outlet of the tool to seal with the port. When the valve is open and the outlet sealed with the port, the slurry in the string is pumped into the borehole around the shoe track by flowing the slurry from the outlet into the borehole through the flow port. As this occurs, gravel collects around the shoe track, and fluid returns in the borehole flow back into the shoe track through a screen disposed toward the track's toe. Once inside the shoe track, the fluid returns communicate through a bypass on the shoe track around the sealed outlet and port. At this point, the fluid returns can pass uphole in the gravel pack assembly.
An annular seal having a sealing member (302k) and method for use is provided for sealing an item of oilfield equipment. The annular seal has an inner diameter for receiving the item of oilfield equipment and a frame (300k). The seal member (302k) is contiguous with the frame (300k). The annular seal is configured for durability, in that it resists wear, inversion, increases lubricity, enables tightness, and/or otherwise generally increases endurance, toughness, and/or permanence.
A pump apparatus has a downhole pump disposed in a wellbore and has a motor at the surface, and a rod string operatively moved by the motor reciprocates the downhole pump in the wellbore. A downhole card indicative of load and position of the downhole pump is generated using surface measurements and a wave equation model having an upstroke damping factor and a downstroke damping factor. Actual fluid load lines are determined from the downhole card for upstrokes and downstrokes of the downhole pump, and calculated fluid load lines for from the strokes are determined from load values distributed on the downhole card.
A method of conducting a gravel pack operation comprising lowering a fluid control assembly 100 into a wellbore and supplying a fluid mixture comprising gravel into an annulus between the fluid control assembly and the wellbore to form a gravel pack. A washout assembly 200 surrounds a pre-determined length of the fluid control assembly 100 to remove gravel pack from around the predetermined length. A tattle-tale sub 220 provides an indication of the location of the washout assembly 200 relative to the fluid control assembly 100. The placement of a cement or inflatable packer is controlled relative to the pre-determined length of the fluid control assembly 100.
Diagnosing a pump apparatus having a downhole pump disposed in a deviated wellbore characterizes axial and transverse displacement of a rod string with two coupled non-linear differential equations of fourth order, which include axial and transverse equations of motion. To solve the equations, derivatives are replaced with finite difference analogs. Initial axial displacement of the rod string is calculated by assuming there is no transverse displacement and solving the axial equation. Initial axial force is calculated using the initial axial displacement and assuming there is no transverse displacement. Initial transverse displacement is calculated using the initial axial force and the initial axial displacement.
Rotating control device related oilfield pressure control is accomplished by upper (26a) and lower (26b) seal members configured to seal around a tubular (40), a chamber (44) defined between the upper and lower seal members; and wherein fluid enters and/or exits the chamber via some device or structure (60, 70). Such a device or structure could be a relief valve (60), a first accumulator (70), a pressure control valve, an orifice, and/or a void space in a seal member in a location which contacts the tubular.
Embodiments of the invention generally relate to a ball valve assembly for use during a cementing operation. In one aspect, a ball valve is provided. The ball valve includes a housing. The ball valve further includes a spherical body disposed within the housing. Additionally, the ball valve includes an actuating member movable relative to the housing between a first position and a second position, wherein the movement of the actuating member causes the spherical body to rotate within the housing. In another aspect, a method of using a ball valve in a cementing operation is provided.
A flow sub (100) for use with a drill string includes: a tubular housing (105) having a longitudinal bore formed therethrough and a flow port formed through a wall thereof; a bore valve (110) operable between an open position and a closed position, wherein the bore valve allows free passage through the bore in the open position and isolates an upper portion of the bore from a lower portion of the bore in the closed position; and a sleeve (121) disposed in the housing and movable between an open position where the flow port is exposed to the bore and a closed position where a wall of the sleeve is disposed between the flow port and the bore; and a bore valve actuator operably coupling the sleeve and the bore valve such that opening the sleeve closes the bore valve and closing the sleeve opens the bore valve.
Methods and apparatus include an expandable packer having a tubing expanded to create a seal in an annulus surrounding the tubing. The tubing includes a non-uniform outer surface configured to cause formation of undulations in a diameter of the tubing upon expansion of the tubing. A plurality of expandable packers may be connected to a tubular string to isolate multiple zones in a wellbore. A production tubular equipped with multiple expandable packers may be installed in the tubular string. The expandable packers may also include non-uniform outer surfaces configured to form undulations upon expansion. The combination of tubular string and production tubular may be used in an enhanced oil recovery application such as injecting steam into a formation to enhance production.
A multi-zone screened frac system combines screens with integrated check valves, frac valves, and optional shunt tubes for slurry dehydration. The system can also include fiber optic technology. In particular, the system uses sliding sleeves and flow devices for each section. The sliding sleeves open with dropped balls or a service tool, and the flow devices have screens and act as check valves. Dehydration tubes can also be used. The system does not require a crossover tool, and in some implementations, the system does not even require a complete service tool.
The present invention generally relates to extrusion-resistant seals for an expandable tubular assembly. In one aspect, a seal assembly for creating a seal between a first tubular and a second tubular is provided. The seal assembly includes an annular member attached to the first tubular, the annular member having a groove formed on an outer surface of the annular member. The seal assembly further includes a seal member disposed in the groove, the seal member having one or more anti-extrusion bands. The seal member is configured to be expandable radially outward into contact with an inner wall of the second tubular by the application of an outwardly directed force supplied to an inner surface of the annular member. Additionally, the seal assembly includes a gap defined between the seal member and a side of the groove.
A method of connecting a first threaded tubular to a second threaded tubular includes: engaging threads of the tubulars; and rotating the first tubular relative to the second tubular, thereby making up the threaded connection. The method further includes, during makeup of the threaded connection: detecting a shoulder position; and after detection of the shoulder position, monitoring for potential yielding of the threaded connection. The method further includes terminating the makeup according to: a first criterion in response to detection of the potential yielding; or a second criterion in response to absence of the potential yielding.
A method of controlling a downhole operation includes: deploying a work string into a wellbore, the work string comprising a deployment string and a bottomhole assembly (BHA); digitally marking a depth of the BHA; and using the digital mark to perform the downhole operation.
E21B 41/00 - Equipment or details not covered by groups
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
78.
METHOD OF INCORPORATING REMOTE COMMUNICATION WITH OILFIELD TUBULAR HANDLING APPARATUS
Appartus and corresponding method for remotely communicating with a device in a wellbore, comprising: an oilfield tubular handling apparatus (200);partial toroidal coil sections (304) integrated with the oilfield tubular handling apparatus, wherein the partial toroidal coil sections form a toroidal coil upon handling a tubular member (102) with the handling apparatus; and a microcontroller for communicating with the device via at least one of signals transmitted or received through the tubular member using the toroidal coil.
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
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrickApparatus for feeding the rods or cables
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
A coupling device includes an upper adapter and a lower adapter. The lower adapter may be pre-installed on a downhole tool and positioned in a wellbore. The upper adapter may be attached to a conveyance and lowered into the wellbore for connection with the lower adapter. The upper adapter may be coupled to the lower adapter by sliding over the lower adapter and applying weight to actuate a locking mechanism. After coupling, axial and torque load may be transmitted from the conveyance to the downhole tool.
The present invention generally relates to an apparatus and method for expanding an anchoring device (100) in a borehole. In one aspect, an anchoring device is provided. The anchoring device includes an expandable tubular (125). The anchoring device further includes a plurality of bands (155) disposed on an outer surface of the expand¬ able tubular. Each band is attached to the tubular at a first connection point (160) and a second connection point (160), wherein each band is configured to bow radially outward as the expandable tubular shortens in length in response to the expansion of the tubular. In a further aspect, a method of attaching an anchoring device in a borehole is provided.
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 43/10 - Setting of casings, screens or liners in wells
A method and apparatus for a pressure relief valve assembly. The valve assembly may be coupled to one or more casings and/or tubular members to control fluid communication therebetween. The valve assembly is a one-way valve assembly that relieves pressure within an annulus formed between adjacent casings and/or tubular members to prevent burst or collapse of the casings and/or tubular members. The valve assembly is resettable downhole.
A pressure relief valve assembly may be coupled to one or more casings and/or tubular members to control fluid communication therebetween. The valve assembly is a one-way valve assembly that relieves pressure within an annulus formed between adjacent casings and/or tubular members to prevent burst or collapse of the casings and/or tubular members. The valve assembly includes a tubular body having a port for fluid communication and a valve ring disposed within the tubular body, the valve ring having a flap for closing the port, wherein the flap is configured to flex from a closed position to an open position in response to a pressure differential. In another embodiment, the valve assembly also includes a retainer sleeve movable from an engaged position for maintaining the flap in a closed position to a disengaged position to allow the flap to open.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
83.
EXPANSION SYSTEM FOR AN EXPANDABLE TUBULAR ASSEMBLY
The present invention generally relates to an apparatus and method for expanding an expandable tubular assembly in a borehole. In one aspect, a system for expanding a tubular (560) having an anchor portion (550) in a borehole is provided. The system includes a running tool (535) configured to position the tubular in the borehole. The running tool including a first expander (520) configured to activate the anchor portion by expanding the tubular (525) to a first diameter. The system further includes a second expander (540) configured to expand the tubular (525) to a second larger diameter, wherein the second expander (540) is movable between a retracted position and an expanded position. In another aspect, a method of expanding a tubular having an anchor portion in a borehole is provided.
A method and apparatus for a pressure relief valve assembly. The valve assembly may be coupled to one or more casings and/or tubular members to control fluid communication therebetween. The valve assembly is a one-way valve assembly that relieves pressure within an annulus formed between adjacent casings and/or tubular members to prevent burst or collapse of the casings and/or tubular members. The valve assembly is resettable downhole.
A pressure relief valve assembly may be coupled to one or more casings and/or tubular members to control fluid communication therebetween. The valve assembly is a one-way valve assembly that relieves pressure within an annulus formed between adjacent casings and/or tubular members to prevent burst or collapse of the casings and/or tubular members. In one embodiment, the valve assembly includes a tubular body having a port for fluid communication between an exterior of the valve assembly and an interior of the valve assembly; a chamber formed in a wall of the tubular body, the chamber in fluid communication with the port; and a closure member disposed in the chamber and configured to control fluid communication through the port in response to a pressure differential.
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 21/10 - Valves arrangements in drilling-fluid circulation systems
86.
LAG CALCULATION WITH CAVING CORRECTION IN OPEN HOLE
A gas analyzer system that can detect atmospheric air gasses in drilling mud is used to calculate an actual lag time in a well. The calculated lag time and a theoretical lag time may be compared to estimate a caving percentage in an open hole section of the well.
A technique for improving the capability of measuring gas losses at the rig surface area uses a predetermined quantity of a preselected gas injected into the drilling fluid used in the drilling rig, which is then detected and compared to measure the gas loss. Various embodiments may use special-purpose gases. Other embodiments may use air or components of air, such as nitrogen or oxygen, as the gas to be detected and measured.
G01N 23/04 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and forming images of the material
A method of completing a subsea wellbore includes providing one or more conductor anchoring assemblies on an outer surface of a conductor; forming the subsea wellbore; positioning the conductor in the subsea wellbore; and energizing the one or more conductor anchoring assemblies into contact with the subsea wellbore, thereby stabilizing the conductor in the subsea wellbore. In yet another embodiment, the method further includes extending the subsea wellbore; positioning a casing inside the conductor, wherein the casing includes a casing anchoring assembly; and energizing the casing anchoring assembly into contact with the conductor.
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
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
The present invention generally relates to a stage tool. In one aspect, a downhole tool for use in a wellbore is provided. The tool includes a body having a bore. The tool further includes a seal assembly attached to the body. The seal assembly having an expandable annular member, a seal member and an expander sleeve, wherein the seal member includes one or more anti-extrusion spring bands embedded within the seal member. The tool further includes a slip assembly attached to the body. The slip assembly includes slips that are configured to engage the wellbore.
The present invention generally relates to an anchor seal for an expandable tubular assembly. In one aspect, an anchoring seal assembly for creating a seal portion and an anchor portion between a first tubular that is disposed within a second tubular is provided. The anchoring seal assembly includes an expandable annular member attached to the first tubular. The annular member has an outer surface and an inner surface. The anchoring seal assembly further includes a seal member disposed in a groove formed in the outer surface of the expandable annular member. The seal member has one or more anti-extrusion spring bands embedded within the seal member, wherein the outer surface of the expandable annular member adjacent the groove includes a rough surface. The anchoring seal assembly also includes an expander sleeve that is configured to radially expand the expandable annular member to create the seal portion and the anchor portion.
A method of drilling a wellbore includes drilling the wellbore by injecting drilling fluid through a drill string extending into the wellbore from surface and rotating a drill bit of the drill string. The drill string further includes a circulation sub having a port closed during drilling. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to the surface via an annulus formed between an outer surface of the tubular string and an inner surface of the wellbore. The method further includes after drilling at least a portion of the wellbore: halting drilling; sending a wireless instruction signal from the surface to a downhole portion of the drill string by articulating the drill string, acoustic signal, or mud pulse, thereby opening the port; and injecting drilling fluid through the drill string and into the annulus via the open port.
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
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
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
E21B 34/00 - Valve arrangements for boreholes or wells
A downhole tool (102) having a throughbore (111) is disclosed for use in a tubular (104) located in a wellbore. The downhole tool has a sealing element (108) configured to seal an annulus (116) between the downhole tool (102) and an inner wall of the tubular (104); at least one flow path (112) formed in the downhole tool, wherein the flow path is configured to allow fluids in the annulus (116) to flow past the sealing element (108) when the sealing element is in a sealed position; and at least one valve (114) in fluid communication with the flow path (112) and configured to allow the fluids to flow through the flow path in a first direction while preventing the fluids from flowing through the flow path in a second direction. A guard (314) may be installed proximate anchor elements (110). The guard (314) extends radially beyond an outer diameter of the anchor elements (110) when the anchor elements are in a retracted position.
An earth removal member with features for facilitating drill-through is provided for drilling with casing or liner applications. In one embodiment, the casing bit includes a tubular body (5); a nose (10) attached to one end of the tubular body (5), wherein the nose (10) includes a blade support (14) and comprises a drillable material; a blade (15) attached to the blade support (14) using mating profiles (31, 43); cutters (20) disposed along the blade (15); and a nozzle (30) disposed in the nose (10).
An electronic control system (10) comprises a first tubular handling tool (20, 30), a sensor (27, 28, 29, 37, 38, 39), and a controller (40). The controller is configured to control actuation of the first tubular handling tool in response to an electronic signal received from the sensor that corresponds to an operational characteristic of the first tubular handling tool. The electronic control system functions as an electronic interlock system to prevent mishandling of a tubular. A method of controlling a tubular handling tool comprises measuring an operational characteristic of the tubular handling tool, communicating the operational characteristic to a controller in the form of an electronic signal, and using the controller to control actuation of the tubular handling tool in response to the measured operational characteristic.
Methods and systems are provided for remotely operating a cementing head. Remotely operating a cementing head ( 202 ) may allow for continued rotation as well as up or down movements (e.g., of a top drive).
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 33/05 - Cementing-heads, e.g. having provision for introducing cementing plugs
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
E21B 47/16 - 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 drill string or casing
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 chargePlugs therefor
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
96.
REMOTE OPERATION OF SETTING TOOLS FOR LINER HANGERS
Methods and systems are provided for remotely operating a setting tool for a liner hanger (402) independent of a ball seating or dart landing. Operating the setting tool independent of the ball seating or dart landing may allow for a sufficient pressure differential to properly set the liner hanger.
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 33/05 - Cementing-heads, e.g. having provision for introducing cementing plugs
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
E21B 47/16 - 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 drill string or casing
97.
MONITORING USING DISTRIBUTED ACOUSTIC SENSING (DAS) TECHNOLOGY
Methods and systems are provided for performing acoustic sensing by utilizing distributed acoustic sensing (DAS) along a length of a conduit, such that the sensing is performed with the functional equivalent of tens, hundreds, or thousands of sensors. Utilizing DAS in this manner may cut down the time in performing acoustic sensing, which, therefore, may make acoustic sensing more practical and cost effective and may enable applications that were previously cost prohibitive with discrete acoustic sensors.
An acoustic control system wirelessly operates a subsea latching assembly (14, 18) or other subsea device, such as an active seal (22). The acoustic control system may control a subsea first accumulator to release its stored hydraulic fluid to operate the latch assembly or other subsea device, such as an active seal. An RCD or other oilfield device may be unlatched or latched with the latching assembly. The acoustic control system may have a surface control unit, a subsea control unit, and two or more acoustic signal devices. A valve may allow switching from an umbilical line system to the acoustic control system accumulator.
E21B 47/14 - 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
Apparatus (10) for restricting a flow of fluid through a bore (14) comprises a bore sealing member (12a) and an actuation assembly for moving the bore sealing member (12a) between first and second configurations. The actuation assembly is configured to isolate first and second end portions (46, 48) of the activation member (12a) from a bore fluid (50). The apparatus (10) provides for moving the bore sealing member (12a) between the first and second configurations without a bore fluid (50) pressure acting on an end portion (46, 48) of the activation member (12a).
Methods and apparatus for conducting fracturing operations using a wellbore fracturing assembly are described. The assembly may be mechanically set and released from a wellbore using a coiled tubing string (110). The assembly may include a pair of spaced apart packers (400A, 400B) for straddling the area of interest, an injection port (300) disposed between the packers (400A, 400B) for injecting fracturing fluid into the area of interest, and an anchor (500) for securing the assembly in the wellbore. At least one of the packers (400A, 400B) includes a pressure balanced mandrel (420). After conducting the fracturing operation, the assembly may be relocated to another area of interest to conduct another fracturing operation.
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