An apparatus can include a telescoping arm (42) having a guiding means (44) and a pivot (70) at opposite ends, the telescoping arm (42) being rotatable about the pivot (70) relative to a spider (28), and the pivot being secured to the spider (28). The apparatus can include an actuator (48) operative to rotate the telescoping arm (42) about the pivot (70), an upper end the actuator (48) is connected to the telescoping arm (42), and a lower end of the actuator (48) is positioned within an outer circumference of the spider (28).
E21B 19/087 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods by means of a swinging arm
2.
METHOD AND APPARATUS FOR CONTROLLING A DOWNHOLE TOOL
A downhole processing apparatus (44) for controlling a downhole tool (100) in a well is disclosed and comprises a downhole processing device (202) providing a first timing operation (TIMER 1; 302) and a second timing operation (TIMER 2; 304); the first timing operation (TIMER 1; 302) being associated with a first downhole sensor (60) capable of at least receiving a signal sent via a first transmission mechanism; the second timing operation (TIMER 2; 304) being associated with a second downhole sensor (210) capable of at least receiving a signal sent via a second transmission mechanism; a data storage device capable of storing data received from the first (60) and second (210) downhole sensors; and the downhole processing device (202) being adapted to be triggered by the first (TIMER 1; 302) and second (TIMER 2; 304) timing operations to check the data storage device, at least once during the respective first (TIMER 1; 302) and second (TIMER 2; 304) timing operations, for data received from the first (60) and/or second (210) downhole sensors and the downhole processing device (202) being adapted to act upon that data to control the downhole tool (100) if instructed to do so.
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
3.
TIME DIVISION MULTIPLEXING (TDM) AND WAVELENGTH DIVISION MULTIPLEXING (WDM) SENSOR ARRAYS
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.
Clustering analysis is used to partition data into similarity groups based on mathematical relationships between the measured variables. These relationships (or prototypes) are derived from the specific correlation required between the measured variables (data) and an environmental property of interest. The data points are partitioned into the prototype-driven groups (i.e., clusters) based on error minimization. Once the data is grouped, quantitative predictions and sensitivity analysis of the property of interest can be derived based on the computed prototypes. Additionally, the process inherently minimizes prediction errors due to the rigorous error minimization during data clustering while avoiding overfitting via algorithm parameterization. The application used to demonstrate the power of the method is pressure gradient analysis.
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
G06K 9/62 - Methods or arrangements for recognition using electronic means
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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
A cementing port collar has an opening sleeve biased from a closed position to an opened position relative to the collar's exit port, and a first restraint temporarily holds the opening sleeve closed. The collar also has a closing sleeve biased from an opened position to a closed position, and a second restraint temporarily holds the closing sleeve opened. During cementing, the first restraint is electronically activated with a first trigger to release the opening sleeve opened so cement slurry can pass out of the collar's exit port to the borehole annulus. When cementing is completed, the second restraint is electronically activated with a second trigger to release the closing sleeve closed to close off the collar to the borehole so the cement can set. The restraints can include bands of synthetic fiber, which are burned by fuses activated by a controller of the collar responding to passage of RFID tags.
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 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 34/00 - Valve arrangements for boreholes or wells
16.
VISCO ELASTIC SURFACTANT CROSSLINKED WITH DIVALENT IONS
Viscoselastic surfactant systems including at least one viscoelastic surfactant and at least one divalent metal compound, where the systems are useable for enhancing oil production in oil wells that coproduce high volumes of gas and/or water and for enhancing gas injection uniformity into injection formations and methods including treating producing or injecting formations with the systems to enhance oil production in treated producing zones or enhance injection efficiency in injection zones.
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
A choke controlling fluid flow in a well has a conduit with an inlet and an outlet, and a flow restrictor comprising first and second choke members (10,20), one of which (20) rotates relative to the other (10) to choke or promote flow. The first and second choke members (10,20) are axially spaced from one another, and have mating faces that are optionally planar, and are axially stacked in the choke. The choke is operated by a shifting tool (50), which grips the inner surface of the rotating choke member (20), and rotates it relative to the other (10), in order to vary the flow.
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 gamma ray detector assembly for a borehole logging system that requires the measure of gamma radiation with optimized gamma ray energy resolution and with fast emission times required to obtain meaningful measurements in high radiation fields. The detector assembly comprises a lanthanum bromide (LaBr3) scintillation crystal and a digital spectrometer that cooperates with the crystal to maximize pulse processing throughput by digital filtering and digital pile-up inspection of the pulses. The detector assembly is capable of digital pulse measurement and digital pile-up inspection with dead-time less than 600 nanoseconds per event. Pulse height can be accurately measured (corrected for pile-up effects) for 2 pulses separated by as little as 150 nanoseconds. Although the invention is applicable to virtually any borehole logging methodology that uses the measure of gamma radiation in harsh borehole conditions, the invention is particularly applicable to carbon/oxygen logging.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
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
29.
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 downhole arrangement (32) comprises first (34) and second (41) members, a lock profile (4) fixed relative to one of the first and second members, and a lock member (10) for engaging the at least one lock profile. A release member (40) is provided which is moveable to selectively lock the lock member in engagement with the lock profile so as to selectively secure the second member relative to the first member. Such a downhole arrangement may permit a releasable connection between the first and second members.
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 downhole catching apparatus (20) comprises a plurality of radially moveable seat members (26) arranged circumferentially around a longitudinal axis, wherein the seat members are moveable between a radially extended configuration which permits passage of an object (64) therethrough and a radially retracted configuration which permits an object (64) to be caught by the apparatus. A releasable lock arrangement (44) is provided for releasably retaining the seat members in the radially extended configuration.
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
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
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 downhole shifting tool (100) for shifting a downhole component (46) comprises a body with a positioning arrangement (108) provided on the body for engaging or interacting with a downhole component to provide alignment of the shifting tool with said component. The tool further includes a connecting member (110) provided on the body and being moveable to selectively engage a connection profile of the downhole component.
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
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 downhole cementing apparatus (10) comprises a body (18)and a sealing arrangement (20) mounted on the body. The cementing apparatus (10) is deployable through a downhole tool (12) with a volume of cement (14). The sealing arrangement (20) is configured to define a varying point of sealing contact axially along the sealing arrangement with an inner surface of a downhole tool (12) as the cementing apparatus (10) is deployed through said tool.
A method for manufacturing a metal structure (130) for use in a downhole assembly comprises plastically deforming at least a portion of the metal structure (130); and heating at least the deformed portion of the metal structure to a temperature below its critical and/or transformation temperature. An assembly for performing the method comprises a production fixture (370) configured to receive the metal structure (130), wherein the production fixture is adapted to undergo heating to a temperature below and/or up to the critical and/or transformation temperature of the metal structure. By heating at least the deformed portion of the metal structure to a temperature below its critical and/or transformation temperature, the metal structure may undergo stress relief, which may help prevent undesirable movement of deformed portion, e.g. collet fingers of a catching apparatus, against the direction of deformation after impact(s) and/or shock(s) from moving objects, in use.
New classes of temporary and/or permanent clay stabilization compositions including at least one quaternary salt of primary amines, secondary amines, tertiary amines, reaction products of these amines with at least one aldehyde, or mixtures and combinations thereof and to methods for making and using same, where the quaternary salts have reduced toxicity.
New classes of temporary and/or permanent clay stabilization compositions including at least one quaternary salt of polyamines or a reaction product of at least one polyamine having an NH moiety with an aldehyde, and to methods for making and using same, where the quaternary salts of polyamines have reduced toxicity.
A method of actuating at least one of a plurality of downhole tools (10) connected to at least one hydraulic fluid line (L1, L2) is disclosed. The method includes the steps of: a) providing each of the downhole tools with a control unit (20) comprising a timer which permits fluid communication between the at least one hydraulic fluid line and the downhole tool during a window of time; and b) controlling the pressure in the at least one hydraulic fluid line for at least a sufficient period of time required to at least actuate the said downhole tool, wherein the said sufficient period of time coincides at least partially with the said window of time. A control unit for operating one or more than one of a plurality of downhole tools connected to at least one hydraulic fluid line is also disclosed as including a timer associated with each of the one or more downhole tools, the timer permitting hydraulic fluid to communicate with the respective downhole tool if supplied via the at least one hydraulic fluid line during a window of time. A timer apparatus for use in downhole wellbore for permitting controlled activation of a downhole tool at a point in time is also disclosed as including a valve associated with an energy storage mechanism and which is arranged to move the valve when the energy is released to actuate the downhole tool. A system of downhole tools is also disclosed as including two or more downhole tools, at least one hydraulic fluid line, wherein each of the two or more downhole tools is connected to the at least one hydraulic fluid line and at least one control unit comprising at least one timer, wherein each of the one or more downhole tools is connected to a timer, said timer permitting hydraulic fluid to communicate with the respective downhole tool. A method of controlling flow downhole in a wellbore is also disclosed.
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
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 41/00 - Equipment or details not covered by groups
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
F15B 11/20 - Servomotor systems without provision for follow-up action with two or more servomotors controlling several interacting or sequentially-operating members
A downhole actuating apparatus (10) comprising a body (12), an object (14) provided on the body, and a sealing arrangement (30) provided on the body and axially spaced from the object. In use, the apparatus (10) is deployed downhole until the object (14) engages an obstacle (44). The sealing arrangement is configured to provide protection for the object during deployment of the apparatus and/or while the apparatus is engaged with the obstacle.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
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 23/08 - Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
46.
DIRECT SLURRY WEIGHT SENSOR FOR WELL OPERATION MIXING PROCESS
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
A system or apparatus for use in downhole communication or detection comprises a downhole arrangement defining a throughbore and primary and secondary elements. One of the primary and secondary elements is provided on the downhole arrangement and the other of the primary and secondary elements is provided in the throughbore. The primary and secondary elements are configurable for coupling of an electromagnetic field therebetween. The primary or secondary element which is provided in the throughbore may be provided on a tool such as a shifting tool which is deployable through the throughbore. The secondary element may be configured to provide the electromagnetic field coupled between the first and second elements with one or more characteristic features. The system may be configured for use, in particular though not exclusively, for communicating information to and/or from a downhole tool in an oil or gas well.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
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
G01N 27/72 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables
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 downhole tool (10) and method for controlling fluid flow into and/or from a formation zone (FZ), the downhole tool (10) comprising a sliding sleeve device (12) disposed between, and forming a fluid coupling between a first screen (14) and a second screen (16), the sliding sleeve device (12) configured to provide axial fluid communication between the screens (14, 16) and to provide selective lateral passage of fluid through the screens (14, 16) into a throughbore (24,36,42) of the downhole tool (10).
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 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
55.
EROSION RESISTANT WELLBORE SCREEN AND ASSOCIATED METHODS OF MANUFACTURE
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
57.
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
58.
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
59.
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
60.
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 downhole apparatus(10) for use in activating a downhole tool (T). The apparatus (10) comprises a seat (18) configured to receive an object, such as a ball (16). The seat (18) comprises a convex object engaging surface(24) for engaging the object.
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
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
An activation apparatus (10) for activating a downhole tool comprising a top sub (12), a bottom sub (14), an outer sleeve (16) having a port (18) and an inner sleeve (20) having a port (22). The apparatus (10) is configurable between a run-in configuration in which the ports (18, 22) are not aligned and an activated configuration in which the ports (18, 22) are aligned and permit lateral passage of fluid through the apparatus (10), the activation apparatus (10) being configured such that application of at least two forces to the activation apparatus (10) transitions the activation apparatus (10) from the run-in configuration to the activated configuration.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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
65.
NOVEL STRONTIUM CARBONATE BRIDGING MATERIALS AND METHODS FOR MAKING AND USING SAME
Drilling fluids were developed including a base fluid, a weighting agent and/or a bridging agent, and a thickening agent, where the weighting agent and/or the bridging agent includes a particulate strontium carbonate having a desired distribution, for weighting agents, the distribution includes particles between 2µ and 5000µ and for bridging agents, the distribution is constructed from particles having specific sizes. Methods making and using the drilling fluids were also discovered.
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.
A flow control method and assembly for an oil or gas well comprises generating a pressure signature in the fluid in a bore of the well comprising a minimum rate of change of pressure, and transmitting the pressure signature to a control mechanism to trigger a change in the configuration of a flow control device in the bore in response to the detection of the pressure signature in the fluid. The flow control device can comprise a barrier, such as a flapper, sleeve, valve or similar. The pressure signature is transmitted via fluid flowing in the bore, typically being injected into the well, optionally during or before frac operations, via fluid being used for the frac operations. The control mechanism typically includes an RFID reader to receive RF signals from tags deployed in the fluid flowing in the bore.
A system (10,100) for isolating a wellbore (12,112) having a fluid flow passage (18,118) extending from surface to a subterranean location has a first, downhole, valve (20,120) and a second, uphole, valve (22,122). The downhole valve (20,120) is located in the wellbore (12,112) at a first subterranean location and the uphole valve (22,122) is located in the wellbore (12,112) at a second subterranean location spaced from the first valve (20,120). Downhole valve (20,120) is operable between a first configuration which permits access through the flow passage (18,118) and a second, well isolation, configuration which isolates the flow passage (18,118) below the valve (20,120). Uphole valve (22,122) is operable between a first configuration which permits access therethrough and a second, isolation, configuration which provides an isolated or isolatable volume (24,124) between the first and second valves (20, 22,120,122). A pressure sensor (26,126) is disposed in the isolated volume (24,124) between the downhole valve (20,120) and the uphole valve (22,122) and, in use, the pressure sensor (26,126) permits a pressure P1 in the isolated volume (24,124) to be measured and/or communicated to a remote location (30).
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 downhole tool (32) comprises a tool housing (34) defining a central bore (35) and including a fluid port (20), and a valve member (40) mounted within the housing (34) and being moveable from a closed position in which the fluid port (20) is blocked to an open position in which the fluid port (20) is opened. The tool (32) further comprises a catching arrangement (41) mounted within the housing (34) and comprising one or more radially moveable seat members (106), and being configurable from a free configuration in which the seat members (106) permit an object (48) to pass through the tool (32), to a catching configuration in which the seat members (106) catch an object (48) passing through the tool (32).
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
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
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 downhole actuator (30) comprises a tubular housing (34) which includes an indexing profile (42) on an inner surface thereof, and an indexing sleeve (46) mounted within the housing (34). The indexing sleeve (46) comprises an engaging arrangement including first and second axially spaced engagement members (52, 54) which cooperate with the indexing profile (42) of the housing (34) to be sequentially engaged by an actuation object (48) passing through a central bore (50) of the indexing sleeve (46) to drive the indexing sleeve (46) one discrete step of movement through the housing (34) towards an actuation site.
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
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
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 flow restrictor for restricting flow in an annulus, the flow restrictor comprising a body and a restrictor assembly mounted on the body, wherein the restrictor assembly is actuatable between a run-in configuration and a set configuration in which at least a portion of the restrictor assembly is radially splayed to thereby substantially restrict flow in the annulus, and wherein the flow restrictor is actuatable by fluid flow over the restrictor assembly above a threshold flow rate to actuate the restrictor assembly from the run-in configuration to the set configuration.
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
74.
CEMENT SYSTEMS INCLUDING A CHIA DERIVED THICKENING AGENT AND METHODS FOR MAKING AND USING SAME
A viscositying system for use in downhole cementing applications including a Chia derived thickening agent and methods for making and using the cements as well as other down hole fluids including a Chia derived thickening agent.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
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
76.
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
The present application relates to systems and methods for use in wellbore completion. Embodiments of the invention relate to a method and system for operating a downhole tool, such as a downhole tool associated with well fracturing.
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
80.
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
84.
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.
Methods relate to using phosphate and/or nitrate brines to reduce hydrate formation in flowlines under conditions conducive for hydrate formation in the absence of the phosphate and/or nitrate brine. The phosphate and/or nitrate brines may include compatible anti- corrosion additives. The accompanying plot of hydrate equilibrium curves shows a phosphate brine and a nitrate brine compared to conventional brines.
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.
A method for determining flow in a medium, comprising applying thermal energy to at least one probe of a pair of probes, the probes configured for placement in the medium and varying the applied thermal energy of the at least one probe to maintain a constant temperature differential between the pair of probes and determining a flow from the applied thermal energy while maintaining the constant temperature differential.
G01F 1/698 - Feedback or rebalancing circuits, e.g. self heated constant temperature flowmeters
F04B 49/00 - Control of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for in, or of interest apart from, groups
F04D 15/00 - Control, e.g. regulation, of pumps, pumping installations, or systems
100.
ANALYSIS OF DRILLSTRING DYNAMICS USING A ANGULAR RATE SENSOR
Downhole drilling vibration analysis uses an angular rate sensor on a drilling assembly. During drilling operations, the sensor measures the angular rate of the drilling assembly. Processing circuitry is operatively coupled to the angular rate sensor and is configured to determine whether torsional type vibrations are occurring during drilling based on the angular rate data. Drilling operations can then be modified to overcome or mitigate the torsional type vibrations.
