An embodiment of a PCD insert comprises an embodiment of a PCD element joined to a cemented carbide substrate at an interface. The PCD element has internal diamond surfaces defining interstices between them. The PCD element comprises a masked or passivated region and an unmasked or unpassivated region, the unmasked or unpassivated region defining a boundary with the substrate, the boundary being the interface. At least some of the internal diamond surfaces of the masked or passivated region contact a mask or passivation medium, and some or all of the interstices of the masked or passivated region and of the unmasked or unpassivated region are at least partially filled with an infiltrant material.
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
C04B 35/52 - Shaped ceramic products characterised by their composition; Ceramic compositions; Processing powders of inorganic compounds preparatory to the manufacturing of ceramic products based on non-oxides based on carbon, e.g. graphite
C04B 35/63 - Preparing or treating the powders individually or as batches using additives specially adapted for forming the products
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
A superhard construction comprises a substrate comprising a peripheral surface, an interface surface and a longitudinal axis and a super hard material layer formed over the substrate and having an exposed outer surface forming a working surface, a peripheral surface extending therefrom and an interface surface. One of the interface surface of the substrate or the interface surface of the super hard material layer comprises one or more projections arranged to project from the interface surface, the height of the one or more projections being between around 0.2 mm to around 1.0 mm measured from the lowest point on the interface surface from which the one or more projections extend.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
B22F 5/00 - Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
B22F 7/08 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools with one or more parts not made from powder
A system and method for logging in a wellbore where sensor assemblies on a logging tool are deployed and landed in the wellbore. After the sensor assemblies are landed in the wellbore and released from the logging tool, the logging tool is pulled uphole. Moving the logging tool uphole from where the sensor assemblies are landed, reduces interference of the logging tool with measurements obtained with the sensor assemblies. The sensor assemblies include sensors for detecting fluid flow, pressure, temperature, fluid density, formation resistivity, and which can be mechanical, optical, acoustic, or electromagnetic.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
A system including a subsea module, a tool hanger, and an in-well tool string coupled to and extending from a lower portion of the tool hanger is provided. The subsea module includes a subsea spool with a main bore formed therethrough, and the main bore includes a tool hanger interface. The subsea module also includes a connector for mounting the subsea module on a subsea component, wherein the connector includes a grip configured to engage the subsea component, and a first seal coupled to the connector and configured to seal the connector against the subsea component. The tool hanger is disposed within the main bore and coupled to the tool hanger interface via at least a second seal configured to seal the tool hanger against the main bore of the subsea spool. The in-well tool string is configured to couple the tool hanger to an in-well tool.
A system and apparatus for providing an apparatus for use in a wellbore. The apparatus includes an apparatus body defining a volume, a propellant disposed within the volume, wherein the propellant has a first burn rate, and at least one propellant insert disposed within the propellant, wherein the propellant insert has a second burn rate, and the second burn rate is different than the first burn rate.
C06B 45/12 - Compositions or products which are defined by structure or arrangement of component or product having contiguous layers or zones
F42B 3/04 - Blasting cartridges, i.e. case and explosive for producing gas under pressure
F42B 3/22 - Elements for controlling or guiding the detonation wave, e.g. tubes
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
C06B 45/00 - Compositions or products which are defined by structure or arrangement of component or product
C06B 31/00 - Compositions containing an inorganic nitrogen-oxygen salt
D03D 23/00 - General weaving methods not special to the production of any particular woven fabric or the use of any particular loom; Weaves not provided for in any other single group
A polycrystalline diamond compact includes a polycrystalline diamond material having a plurality of grains of diamond bonded to one another by inter-granular bonds and an intermetallic gamma prime (γ′) or κ-carbide phase disposed within interstitial spaces between the inter-bonded diamond grains. The ordered intermetallic gamma prime (γ′) or κ-carbide phase includes a Group VIII metal, aluminum, and a stabilizer. An earth-boring tool includes a bit body and a polycrystalline diamond compact secured to the bit body. A method of forming polycrystalline diamond includes subjecting diamond particles in the presence of a metal material comprising a Group VIII metal and aluminum to a pressure of at least 4.5 GPa and a temperature of at least 1,000° C. to form inter-granular bonds between adjacent diamond particles, cooling the diamond particles and the metal material to a temperature below 500° C., and forming an intermetallic gamma prime (γ′) or κ-carbide phase adjacent the diamond particles.
A method of predicting behavior of a drilling assembly includes: generating a mathematical representation of a geometry of each of a plurality of components of a drilling assembly, the plurality of components including a plurality of cutters and one or more additional components configured to at least one of: support the plurality of cutters and operably connect the plurality of cutters to the drill string, the one or more additional components including a drill bit crown; simulating one or more operating conditions incident on the drilling assembly representation, and simulating an interaction between the plurality of components and an earth formation; and predicting physical responses of the drilling assembly representation to the one or more conditions.
G06G 7/48 - Analogue computers for specific processes, systems, or devices, e.g. simulators
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
G01V 99/00 - Subject matter not provided for in other groups of this subclass
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
Sensor data is received characterizing operational data associated with a machine. A data analytic specification is received from a user. The received operational data can be processed using the data analytic. A visual representation of the processed operational data can be rendered, within a graphical user interface display space. A digital model characterizing the machine can be generated based on user input received in the graphical user interface. Additional sensor data can be received. The digital model can be updated based on the received additional sensor data. A recommendation for modifying an input value and/or an operational parameter of the machine can be determined using the updated model. The recommendation can be rendered within the graphical user interface space. Related apparatus, systems, techniques and articles are also described.
G05B 13/04 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric involving the use of models or simulators
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 45/00 - Measuring the drilling time or rate of penetration
9.
Movable cutters and devices including one or more seals for use on earth-boring tools in subterranean boreholes and related methods
A rotatable element for an earth-boring tool in a subterranean borehole includes a rotatable element and a stationary element. The rotatable element and stationary element include a seal arrangement between the rotatable element and the stationary element. The seal arrangement encloses a volume that remains substantially constant as the rotatable element moves relative to the stationary element.
E21B 10/25 - Roller bits - characterised by bearing, lubrication or sealing details - characterised by sealing details
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
A well tool includes a first component, a second component having a passage for receiving the first component, and an anchor assembly. The anchor assembly includes at least one anchor positioned on the first component that is received by at least one profile formed on an inner surface defining the passage of the second component. Either or both of the at least one profile and the at least one anchor include a ramp section that has a ramp contour defined by a ramp tangent. The ramp tangent forms an acute angle with a longitudinal axis of the borehole. A related method includes the steps of forming at least one profile in the second component, the at least one profile including a ramped section; disposing at least one anchor in the first component; and lowering the first component relative to the second component until the first anchor and the first profile align the first component and the second component in a predetermined relative alignment.
E21B 17/046 - Couplings; Joints 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. sinking; Simultaneously drilling and casing boreholes
An embodiment of a method of detecting and correcting for spiraling in a downhole carrier includes: deploying the carrier in a borehole in an earth formation as part of a subterranean operation; acquiring time based data from at least one sensor disposed at the carrier; acquiring time and depth data, the time and depth data correlating time values with depths of the carrier; generating a depth based profile based on the time based data and the time and depth data; generating a frequency profile by transforming the depth based profile into the frequency domain; detecting a spiraling event based on an amplitude of the frequency profile; and taking corrective action based on detecting the spiraling event.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
G05B 13/02 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric
12.
Earth-boring tools with reduced vibrational response and related methods
Earth-boring tools may include a body, blades extending outward from the body, and cutting elements secured to the blades. An entirety of a first blade may exhibit a first, constant or continuously variable radius of curvature different from a second, constant or continuously variable radius of curvature of at least another portion of a second blade. Methods of making earth-boring tools may involve forming at least a portion of a first blade extending outward from a body to exhibit a first radius of curvature. An entirety of a second blade extending outward from the body may be formed to exhibit a second, different, constant or continuously variable radius of curvature. Cutting elements may be secured to the first and second blades.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
Systems and methods for downhole component monitoring including a monitored component doped with a pre-selected neutron absorbent, the monitored component being part of a downhole tool and a neutron monitoring system positioned relative to the monitored component. The neutron monitoring system includes a neutron source positioned at a first location relative to the monitored component and a neutron detector positioned at a second location relative to the monitored component, the neutron detector configured to detect neutrons from the neutron source and count said detected neutrons. A control unit is in communication with the neutron detector and configured to determine a status of the monitored component from the neutron count received from the neutron detector.
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
14.
Earth-boring tools including passively adjustable, aggressiveness-modifying members and related methods
Earth-boring tools may include a body and a passively adjustable, aggressiveness-modifying member secured to the body. The passively adjustable, aggressiveness-modifying member may be movable between a first position in which the earth-boring tool exhibits a first aggressiveness and a second position in which the earth-boring tool exhibits a second, different aggressiveness responsive to forces acting on the passively adjustable, aggressiveness-modifying member.
BP Exploration Operating Company Limited (United Kingdom)
Inventor
Curry, David A.
Pessier, Rudolf Carl
Spencer, Reed W.
Kuesters, Andrea
Wingate, John
Abstract
Methods of drilling earth formations may involve removing a portion of an underlying earth formation utilizing cutting elements of an earth-boring drill bit. A rotational speed of the drill string may be sensed utilizing a first sensor. A rate of penetration of the drill string during advancement of the earth-boring drill bit may be sensed utilizing a second sensor. An instantaneous average depth of cut of cutting elements of the earth-boring drill bit may be determined utilizing a control unit to calculate the instantaneous average depth of cut based on a sensed rotational speed of the drill string and a sensed speed of advancement of the drill string. The weight on the earth-boring drill bit may be increased utilizing the drawworks when the instantaneous average depth of cut is less than the predetermined minimum depth of cut.
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 45/00 - Measuring the drilling time or rate of penetration
Systems, methods, and devices for evaluation of an earth formation intersected by a borehole using a logging tool. Methods include performing EM logging in a borehole intersecting an earth formation using a measurement signal from an antenna system in the borehole, the measurement signal dependent upon a parameter of interest of the formation and at least one antenna system parameter of the antenna system, comprising feeding a calibration signal into a signal path of the antenna system to generate a resultant signal; estimating at least one value of the at least one antenna system parameter by using the resultant signal; and performing further logging operations in dependence upon the at least one value of the at least one antenna system parameter. The calibration signal comprises at least two calibration subsignals with a first calibration subsignal having a first frequency and a second calibration subsignal having a second frequency.
Methods of using a component in a subterranean wellbore include positioning a component including a degradable thermoset polymer material in a wellbore location, obstructing flow with the component, exposing the component to an acidic solution to degrade the selectively degradable thermoset polymer material and to remove the component from the wellbore location, and flowing a fluid through the wellbore location where the component was positioned. Methods of forming a component of a wellbore system include forming at least a portion of the component to comprise a degradable thermoset polymer material. Wellbore systems include at least one component including a selectively degradable thermoset polymer material. The selectively degradable thermoset polymer material may be a polyhexahydrotriazine (“PHT”) material.
E21B 43/28 - Dissolving minerals other than hydrocarbons, e.g. by an alkaline or acid leaching agent
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
Core sample catchers for use with coring tools for obtaining core samples from subterranean formations may include at least one flap catcher member configured to be movably coupled to an inner barrel of the coring tool and configured to move between an open position and a closed position. A piston member including a central bore may be disposed in a passageway extending through the inner barrel. The piston member may be configured to move between a first position and a second position, the piston member configured to retain the at least one flap catcher member in the open position when the piston member is in the first position, and allow flap catcher member to move into the closed position when the piston member is in the second position.
E21B 25/10 - Formed core retaining or severing means
E21B 25/14 - Formed core retaining or severing means mounted on pivot transverse to core axis
E21B 25/00 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels, core extractors
E21B 25/04 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels, core extractors the core receiver being insertable into, or removable from, the borehole without withdrawing the drilling pipe the core receiver having a core forming cutting edge or element, e.g. punch type core barrels
A system and method for logging in a wellbore where sensor assemblies on a logging tool are deployed and landed in the wellbore. After the sensor assemblies are landed in the wellbore and released from the logging tool, the logging tool is pulled uphole. Moving the logging tool uphole from where the sensor assemblies are landed, reduces interference of the logging tool with measurements obtained with the sensor assemblies. The sensor assemblies include sensors for detecting fluid flow, pressure, temperature, fluid density, formation resistivity, and which can be mechanical, optical, acoustic, or electromagnetic.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
20.
Activation modules for obstructing entrances to inner barrels of coring tools and related coring tools and methods
Activation modules for selectively sealing entrances to inner barrels of coring tools may include an activator body and an activation rod movable between a first position and a second position. A locking element may temporarily hold the activator body in place and a sealing element may form a temporary seal. The activation rod may include a locking portion, a releasing portion of a smaller diameter, a sealing portion, and an unsealing portion of a smaller diameter. The locking portion may be aligned with the locking element and the sealing portion may be aligned with the sealing element when the activation rod is in the first position. The releasing portion may be aligned with the locking element and the unsealing portion may be aligned with the sealing element when the activation rod is in the second position.
E21B 25/00 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels, core extractors
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
Methods of determining a pH of a wellbore fluid within a wellbore in communication with a subterranean formation comprise introducing carbon quantum dots into a wellbore fluid, exposing the wellbore fluid to radiation from an electromagnetic radiation source, and measuring at least one fluorescence property of the carbon quantum dots within the wellbore fluid to determine a pH of the wellbore fluid. Related methods of determining a pH of a fluid within a wellbore extending through a subterranean formation are also disclosed.
Core jam indicators for use with coring tools include a plug coupled with an inner barrel and configured to selectively close the entrance of the inner barrel. The plug has at least one fluid port extending through a wall of the plug between an interior and an exterior of the plug. The mandrel at least partially covers the at least one fluid port of the plug in an activated position and the at least one fluid port is at least partially uncovered by the mandrel in a deactivated position. The mandrel is coupled to the inner barrel. A piston force acting on the mandrel resulting from a pressure difference above and below the mandrel acts over an area smaller than a maximum transverse cross-sectional area of the inner barrel. Coring tools include such core jam indicators. Components are provided and assembled to form such core jam indicators.
An apparatus for detecting over-torquing or un-torquing of a threaded connection between components in a borehole penetrating the earth includes: a string of components coupled in series by a threaded connection; a transmission line attached to each component; a signal coupler in communication with the transmission line and disposed on each component at each threaded connection, the signal coupler being configured to transmit the signal to an adjacent signal coupler on an adjacent coupled component in order to transmit a signal along the transmission line attached to the adjacent coupled component; a receiver configured to receive the signal; and a processor in communication with the receiver and configured to: (i) determine a difference between a characteristic of the signal and the characteristic of a reference signal and (ii) transmit an alert signal signifying that the threaded connection is over-torquing or un-torquing in response to the difference exceeding a threshold value.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
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 31/00 - Fishing for or freeing objects in boreholes or wells
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
G01P 15/16 - Measuring acceleration; Measuring deceleration; Measuring shock, i.e. sudden change of acceleration by evaluating the time-derivative of a measured speed signal
24.
Methods and apparatus for measuring hydrogen sulfide in downhole fluids
A method of determining a concentration of hydrogen sulfide in a fluid comprises exposing a sensor to the fluid, the sensor comprising a pair of electrodes defining a gap therebetween and a sensing material bridging the gap between the electrodes, measuring a value of an electrical parameter of the sensor at an applied frequency of greater than about 10 kHz and a voltage of less than about 1.0 volt when the sensor is exposed to the fluid, and determining the concentration of hydrogen sulfide in the fluid based at least in part on the measured value of the electrical parameter. Related apparatuses and methods are also disclosed.
G01V 3/20 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
G01N 27/12 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of a solid body in dependence upon reaction with a fluid
An apparatus for determining torque on bit and bending forces in a drilling assembly. The apparatus includes a body having an inner bore defined by an inner wall and having an outer wall, the body also including first and second light bores disposed between the inner wall and the outer wall and a light emitting assembly arranged and configured to cause a light beam to enter the first and second light bores. The assembly further includes first and second light sensors disposed in or at an end of the first and second light bores, respectively, that measure a location where light that enters the first and second light bores contacts the sensors.
G01N 3/20 - Investigating strength properties of solid materials by application of mechanical stress by applying steady bending forces
G01L 1/24 - Measuring force or stress, in general by measuring variations of optical properties of material when it is stressed, e.g. by photoelastic stress analysis
G01L 3/00 - Measuring torque, work, mechanical power, or mechanical efficiency, in general
26.
Methods and systems for monitoring well integrity and increasing the lifetime of a well in a subterranean formation
A system for increasing the detecting degradation of a wellbore. The system comprises a computer memory configured for storing computing instructions and a processor operably coupled to the computer memory. The system comprises a sensor operably coupled to the computer memory and is configured to determine the presence of at least one chemical species indicative of degradation of the wellbore in a fluid exiting the wellbore. Methods of monitoring a wellbore for corrosion or other degradation of one or more components of wellbore equipment are disclosed as are methods of increasing the lifetime of a wellbore.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
C09K 8/03 - Specific additives for general use in well-drilling compositions
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
27.
Optical sensors for downhole tools and related systems and methods
A method of detecting at least one of an analyte or a condition of a fluid within a subterranean formation includes operably coupling a radiation source to at least one optical fiber coupled to a sensor having optically sensitive materials including at least one of chromophores, fluorophores, metal nanoparticles, or metal oxide nanoparticles dispersed within an optically transparent permeable matrix material. The sensor is contacted within a wellbore with a fluid and the fluid is passed through at least a portion of the sensor. Electromagnetic radiation is transmitted from the radiation source through at least one optical fiber to the sensor and at least one of an absorbance spectrum, an emission spectrum, a maximum absorption intensity, or a maximum emission intensity of electromagnetic radiation passing through the sensor after contacting at least some of the optically sensitive materials with the fluid is measured. Additional methods of determining a concentration of hydrogen sulfide in a fluid within a subterranean formation and related downhole optical sensor assemblies are disclosed.
Methods and apparatus configured to evaluate a volume of interest of an earth formation intersected by a borehole. Apparatus comprise a transceiver electrode on the tool body configured to provide electrical current to the earth formation; a return electrode configured to receive the electrical current returning from the earth formation; a multi-function electrode on the resistivity imager tool; and an electrical system configured to provide current measurements at the transceiver electrode. In the first operational mode, the electrical system maintains the tool body at a first electrical potential, and maintains the multi-function electrode and the transceiver electrode at a second electrical potential; and in the second operational mode, the electrical system maintains the tool body at the first electrical potential, maintains the multi-function electrode at the first electrical potential, and maintains the transceiver electrode at the second potential.
G01V 3/26 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
29.
Flow off downhole communication method and related systems
A method enables communication with downhole tools during a “flow off” condition by energizing at least one sensor and a controller using a local power source only after flow of drilling fluid has been reduced below the threshold flow rate value. Thereafter, the method involves generating the at least one predetermined pattern into the wellbore, detecting the at least one predetermined pattern using the at least one sensor and the controller, and transmitting a signal using the controller in response to the detected at least one predetermined pattern.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
A flowmeter for use in a borehole that includes a transmitter and receivers spaced axially away from the transmitter. Energizing the transmitter creates electrical field lines that extend between the transmitter and the receivers, and that pass through fluid flowing past the flowmeter. The magnitude of the electrical field lines at each of the receivers is measured, and varies in response to different types of fluid flowing past the flowmeter, and changes in phase of the fluid. Example transmitters and receivers include coils and electrodes. The transmitters and receivers can define elongate arrays, where the arrays are arranged parallel to, oblique, or perpendicular to an axis of the borehole. Multiple array orientations provide a radial cross sectional image of the flowing fluid. Thus not only can multi-phase flow be detected, but the type of flow regime can be identified.
G01F 1/58 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using electric or magnetic effects by electromagnetic flowmeters
G01V 3/20 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
G01V 3/28 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
G01F 1/74 - Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
A system and method for stimulating hydrocarbon production from a wellbore that perforates the formation around the wellbore in strategic locations so that fractures can be formed in the formation having specific orientations. The system includes deep penetration perforators that extend past a portion of the formation adjacent the wellbore having locally high internal stresses (a stress cage); and big hole perforators that form perforations with a larger entrance diameter. The perforators form perforations in the formation that are axially consolidated along the wellbore. After perforating, the wellbore is hydraulically fractured with high pressure fluid, which creates fractures in a formation surrounding the wellbore that extend radially outward from the perforations. Creating perforations that are axially consolidated reduces the chances of forming competing fractures in the formation during fracturing.
A hydraulic tool includes a stator, a rotor, and a removable coating. At least one of the stator and the rotor comprises a resilient material. The removable coating has a thickness selected to compensate for expected swelling of the resilient material or an expected contraction of a clearance between the rotor and the stator based on thermal expansion. The removable coating is disposed on a surface of at least one of the rotor and the stator, and the removable coating is formulated to be removed during operation of the hydraulic tool. A method of operating a hydraulic tool includes passing a fluid through the hydraulic tool during rotation of the rotor within the stator and removing at least a portion of the removable coating responsive to rotation of the rotor within the stator as a volume of the resilient material increases responsive to contact with the fluid passing through the hydraulic fluid.
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
F04C 18/107 - Rotary-piston pumps specially adapted for elastic fluids 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
F01C 1/10 - Rotary-piston machines or engines 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
C23C 16/44 - Chemical coating by decomposition of gaseous compounds, without leaving reaction products of surface material in the coating, i.e. chemical vapour deposition (CVD) processes characterised by the method of coating
33.
Coring tools with improved reliability during core jams, and related methods
An inner barrel assembly for use with a coring tool may include a sleeve located coaxially within an inner barrel in a telescoping manner. The core barrel assembly may also include a cap located above a top end of the sleeve when the inner barrel assembly is in an initial coring position. The cap may include a skirt having a portion extending downwardly from the cap. A coring tool including an inner barrel assembly and methods of forming an inner barrel assembly are also disclosed.
A method of detecting an analyte includes vaporizing at least a portion of a fluid within a wellbore, passing the vaporized fluid adjacent a chemiresistive sensing element coupled to a drill string within the wellbore and sensing a resistivity of the chemiresistive sensing element. A sensor for detecting an analyte includes an expansion device for vaporizing a portion of a fluid within a wellbore, a chemiresistive sensing element configured to contact the vaporized fluid within the wellbore and a controller configured to pass a current through the chemiresistive sensing element and calculate a resistance of the chemiresistive sensing element in contact with the gaseous portion of the fluid. An earth-boring tool may include a bit body coupled to a drill string and the sensor.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01N 27/414 - Ion-sensitive or chemical field-effect transistors, i.e. ISFETS or CHEMFETS
G01N 27/12 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of a solid body in dependence upon reaction with a fluid
G01N 27/04 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
A superelastic metal seal for use in a downhole tool, wherein the superelastic metal seal may be formed from a superelastic Ni—Ti alloy. The superelastic Ni—Ti alloy may be prestrained with a permanent strain. Superelasticity may be imparted to the superelastic Ni—Ti alloy through a thermal treatment process or through prestraining the superelastic Ni—Ti alloy. The superelastic Ni—Ti alloy may exhibit superelastic behavior. The superelastic Ni—Ti alloy may not exhibit shape memory behavior.
E21B 41/00 - Equipment or details not covered by groups
C22F 1/10 - Changing the physical structure of non-ferrous metals or alloys by heat treatment or by hot or cold working of nickel or cobalt or alloys based thereon
C22C 19/03 - Alloys based on nickel or cobalt based on nickel
F16J 15/3284 - Sealings between relatively-moving surfaces with elastic sealings, e.g. O-rings characterised by their structure; Selection of materials
F16J 15/328 - Manufacturing methods specially adapted for elastic sealings
An apparatus for investigating a subsurface volume may include an acoustic transducer disposed in an enclosure and generating acoustical signals, an electronics assembly disposed in the enclosure and controlling the acoustic transducer, and a lens assembly. The lens assembly may be disposed in the enclosure and next to the acoustic transducer. The lens assembly may be formed of a plurality of cells. Each cell may be formed as a column oriented transverse to a direction of travel of the acoustical signals. Each cell may have a hub, a plurality of spokes radiating from the hub, and a plurality of fingers circumferentially distributed around the hub. The hub, spokes, and fingers may be oriented to cause the acoustic waves to travel at a different speed in each of three orthogonal directions. A related method uses the apparatus in a wellbore.
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
A method of forming a downhole seal between inner and outer tubulars. The method including bonding a sealing element to an insert with a bond that bonds at temperatures less than a first temperature and increasingly breaks down at temperatures higher than the first temperature. Defeating the bond between the sealing element and the insert at a second temperature higher than the first temperature; and, subsequently forming a seal between the inner and outer tubulars with the sealing element. Also included is a downhole sealing apparatus.
A distributed temperature sensor (DTS) system includes a light source; a length of fiber filter having been hydrogen darkened prior to assembly of the system; and a DTS fiber. A method for making a filter for a DTS system.
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
A method of forming a cutting element for an earth-boring tool includes forming a table of superabrasive material over a substrate in an HTHP environment such that the table of superabrasive material is bonded to the substrate. The table of superabrasive material and the substrate form a cutting element. The method includes removing the cutting element from the HTHP environment, ascertaining predictable residual stresses within the table of superabrasive material, and marking the cutting element with at least one mark. The at least one mark provides indication of a region of the table of superabrasive material having a maximum or minimum residual stress therein. An additional method includes obtaining such a marked cutting element and affixing the cutting element on an earth-boring tool in a preferential orientation as indicated at least partially by the mark.
A system for determining at least one property of at least one fluid in at least one subterranean formation comprises a fluid delivery system configured and positioned to deliver a fluid into at least one of at least one subterranean formation and a wellbore extending through the at least one subterranean formation. The system comprises a radiation source within the wellbore, the radiation source configured to generate excitation radiation, carbon quantum dots disposed in the fluid, and a detector within the wellbore, the detector configured to measure at least one fluorescence property of the carbon quantum dots. Related methods of determining a property of a wellbore and methods of forming the carbon quantum dots are also disclosed.
G01V 8/16 - Detecting, e.g. by using light barriers using one transmitter and one receiver using optical fibres
C25B 1/00 - Electrolytic production of inorganic compounds or non-metals
G01N 21/77 - Systems in which material is subjected to a chemical reaction, the progress or the result of the reaction being investigated by observing the effect on a chemical indicator
A cable retainer for a downhole tubing string includes a body; a detent extending from the body; a relief between the detent and the body facilitating deflection of the detent to allow passage of a cable; and a detent lip extending from the detent. A method for securing a cable to a tubular.
Cutting structures for use with downhole tools in subterranean boreholes include a blade, a plurality of primary cutting elements coupled to the blade, and at least one secondary element rotationally leading the plurality of primary cutting elements in a direction of intended rotation of the cutting structure. The at least one secondary element is coupled to the blade proximate a leading surface of the blade and comprises at least one of a rubbing surface and a cutting surface. An exposure of at least one primary cutting element of the plurality of primary cutting elements is greater than an exposure of the at least one secondary element. Downhole tools such as reamers include cutting structures. Methods of enlarging a subterranean borehole include reaming a borehole with cutting structures.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
43.
Method of estimating multi-phase fluid properties in a wellbore utilizing acoustic resonance
A system and method of estimating properties of a wellbore fluid that directs the fluid through a cavity, and generates acoustic waves in the fluid while in the cavity. The acoustic waves are generated by oscillating an electroactive material over a range of frequencies. An electrical admittance spectra of the electroactive material is measured over the range of frequencies; where the electrical admittance spectra includes the magnitude, real, and imaginary components. Differences between the maximum values for each component and a vacuum electrical spectra are calculated, the differences are substituted into estimator equations to estimate the fluid properties. Electrical admittance spectra of the electroactive material was simulated for a series of known fluids flowing through the cavity, and a multi-regression statistical analysis was then used to derive the estimator equations.
B06B 1/06 - Processes or apparatus for generating mechanical vibrations of infrasonic, sonic or ultrasonic frequency making use of electrical energy operating with piezoelectric effect or with electrostriction
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 29/036 - Analysing fluids by measuring frequency or resonance of acoustic waves
44.
Density measurements using detectors on a pulsed neutron measurement platform
An apparatus for estimating a property of an earth formation and a borehole fluid includes a carrier configured to be disposed in a borehole, and a pulsed neutron measurement assembly including a pulsed neutron source configured to emit neutrons into the borehole and the earth formation, and a gamma ray detector. The apparatus also includes a fluid density measurement assembly including the gamma ray detector and a gamma ray source configured to irradiate a borehole fluid with gamma rays. The gamma ray detector is positioned relative to the gamma ray source to detect both of: gamma rays resulting from neutron interactions and gamma rays emitted from the borehole fluid in response to irradiation from the gamma ray source. The apparatus further includes a processor configured to differentiate a pulsed neutron gamma ray spectrum associated with the interactions from a density gamma ray spectrum.
G01N 9/24 - Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity by observing the transmission of wave or particle radiation through the material
G01V 5/14 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using a combination of several sources, e.g. a neutron and a gamma source
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
G01V 5/12 - Prospecting or detecting by the use of nuclear 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
G01T 1/208 - Circuits specially adapted for scintillation detectors, e.g. for the photo-multiplier section
45.
Communications protocol for downhole data collection
A method of managing data obtained in a borehole is provided. The method includes monitoring a characteristic with at least one sensor and obtaining raw data therefrom; indexing the raw data with the at least one sensor; recording the indexed data with the at least one sensor; forming a data packet with the at least one sensor, the data packet including at least a portion of the indexed data and index information; and transmitting the data packet in a predetermined segment of a communication protocol.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A method for transmitting data from a downhole location to a location at the surface of the earth includes determining a minimum value and a maximum value of M-samples of data values, determining a keycode for the M-samples of data values that provides an indication of the maximum and minimum values of the M-samples, and encoding the keycode and the data values into one or more encoded words. The one or more encoded words are then transmitted as an acoustic signal in drilling fluid by modulating a mud-pulser. The acoustic signal is received by a transducer uphole from the mud-pulser and converted into an electrical signal. The electrical signal is demodulated into a received encoded word, which is decompressed into the M-samples in accordance with the keycode. The M-samples are then received by a computer processing system disposed as the surface of the earth.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
H03M 7/00 - Conversion of a code where information is represented by a given sequence or number of digits to a code where the same information is represented by a different sequence or number of digits
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
47.
Expandable reamers having nonlinearly expandable blades, and related methods
Expandable reamers for enlarging a borehole in a subterranean formation include a tubular body, at least one curved blade track carried by the tubular body, and at least one blade engaged with the at least one blade track and configured to slide along the curved blade track along a curved path between a first retracted blade position and a second expanded blade position. To form such an expandable reamer, a tubular body having at least one curved blade track carried by the tubular body may be formed, and at least one blade may be engaged with the blade track. The blade and blade track may be configured such that the blade slides along the blade track along a curved path between a retracted position and an expanded position. Such expandable reamers may be used to enlarge boreholes in subterranean formations.
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
B23P 15/46 - Making specific metal objects by operations not covered by a single other subclass or a group in this subclass cutting tools reaming tools
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
48.
Method of measuring acoustic energy impinging upon a cable
A method of measuring acoustic energy impinging upon a cable includes, interrogating at least one optical fiber of the cable with electromagnetic energy, the at least one optical fiber is nonconcentrically surrounded by and strain locked to a sheath of the cable, monitoring electromagnetic energy returned in the at least one optical fiber, and determining acoustic energy impinging on the cable.
A flapper valve includes a valve body having a hinge member. A flapper is pivotally mounted to the valve body through the hinge member. At least one of the valve body and the flapper includes a multi-stage valve seat. The multi-stage valve seat includes a first sealing zone and a second sealing zone that is distinct from the first sealing zone. The first sealing zone is configured to provide pressure containment at the valve body when the flapper is exposed to a first pressure and the second sealing zone is configured to provide pressure containment at the valve body when the flapper is exposed to a second pressure that is greater than the first pressure.
A cement isolation fluid for use in a wellbore during a cementing operation includes an aqueous carrier fluid and a preformed synthetic polymer swellable in the carrier fluid, in an amount effective to isolate a cement slurry from another drilling fluid present in the wellbore. A method of cementing a wellbore comprising a drilling fluid includes injecting the cement isolation fluid into the wellbore; injecting a cement slurry into the wellbore; and hardening the cement in the slurry to cement the wellbore.
An apparatus for sensing a parameter beneath a surface of the earth includes an optical fiber disposed beneath a surface of the earth and comprising at least one fiber Bragg grating sensor configured to sense the parameter and a wide-band light source disposed beneath the surface of the earth and configured to emit light in a wide band of wavelengths to illuminate the at least one fiber Bragg grating. An optical interrogator is disposed beneath the surface of the earth and configured to receive light reflected by the at least one fiber Bragg grating sensor and to transform a shift in wavelength of the reflected light into a variation of light intensity. A photo-sensor is configured to measure intensity of light received from the optical interrogator. Electronics are coupled to the photo-sensor and configured to measure a voltage representing the light intensity at the photo-sensor to sense the parameter.
G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
G01V 8/16 - Detecting, e.g. by using light barriers using one transmitter and one receiver using optical fibres
52.
Coring tools for managing hydraulic properties of drilling fluid and related methods
A coring bit for use on a coring tool for extracting a sample of subterranean formation from a wellbore includes a bit body having a cavity, wherein a throat portion of the cavity extends into the bit body from a face of the bit body. The coring bit includes a sleeve disposed within the cavity of the bit body, the sleeve configured to separate a face discharge channel and a throat discharge channel. The face discharge channel is located radially outward of the sleeve and the throat discharge channel is located radially inward of the sleeve. A method of repairing a such a coring bit includes removing the sleeve from the cavity of a bit body.
A cell for manipulating an acoustic wave includes a plurality of spokes radiating from a hub and a plurality of concentrically arranged leaves. Each leaf is supported by at least one spoke and is formed by a plurality of circumferentially distributed fingers. Each finger is connected to at least one spoke.
Expandable reamer assemblies include an expandable reamer module and an activation module. An outer tubular body of the activation module is rigidly coupled to a tubular body of the expandable reamer module, and an activation member of the activation module is coupled to a sleeve of the expandable reamer module, the sleeve coupled to at least one blade and configured to move the at least one blade into an extended position. The sleeve moves axially responsive to axial movement of the activation member. Bottom-hole assemblies include an expandable reamer module and an activation module. The activation module is coupled to the expandable reamer module and configured to provide a motive force to the sleeve to move the sleeve opposite a direction of flow of drilling fluid. Methods of using expandable reamer modules include pairing two substantially identical expandable reamer modules and two respective different activation modules.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 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 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
55.
Sponge liner sleeves for a core barrel assembly, sponge liners and related methods
A liner tube for a core barrel assembly includes a substantially cylindrical sleeve having an inner surface configured to be coupled to a layer of material that is configured to absorb or adsorb formation fluids or parts of formation fluids. At every longitudinal location of the sleeve with respect to a longitudinal axis of the sleeve, a transverse cross-section of a wall of the sleeve may include at least one gap extending radially through the entire wall of the sleeve, such that the at least one gap separates a portion of the sleeve wall on one circumferential side of the at least one gap from another portion of the sleeve wall on an opposite circumferential side of the at least one gap. The sleeve has flexibility in a circumferential direction greater than that of a sleeve without a gap extending radially through an entire wall of the sleeve at a transverse cross-section of the sleeve at every longitudinal location of the sleeve. The sleeve may include at least two circumferential segments in contact with an elastic element extending in a circumferential direction. Methods of forming a liner for a core barrel assembly, methods of building a coring tool with such a liner, and methods of coring a formation material are also disclosed.
E21B 25/06 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels, core extractors the core receiver having a flexible liner or inflatable retaining means
56.
Arrayed wave division multiplexing to improve spatial resolution of IOFDR fiber Bragg sensing system
A downhole property measurement apparatus includes an optical fiber having a series fiber Bragg gratings with interleaved resonant wavelengths such that adjacent fiber Bragg gratings have different resonant wavelengths and a difference between adjacent resonant wavelengths is greater than a dynamic wavelength range of each of the adjacent fiber Bragg gratings. An optical interrogator is in optical communication with the optical fiber and configured to emit a frequency domain light signal having a swept wavelength for a first time duration and a chirp having a modulation of amplitude with a varying of wavelength for a second time duration that is less than the first time duration. A return light signal is transformed by the optical interrogator into a time domain to determine a resonant wavelength shift and corresponding location of each of the gratings. A processor converts the resonant wavelength shifts into the downhole property.
G01D 5/353 - Mechanical means for transferring the output of a sensing member; Means 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 converting; Transducers 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
G01V 8/16 - Detecting, e.g. by using light barriers using one transmitter and one receiver using optical fibres
G02B 6/34 - Optical coupling means utilising prism or grating
G01M 11/00 - Testing of optical apparatus; Testing structures by optical methods not otherwise provided for
A method of completing a wellbore is disclosed that in one non-limiting embodiment includes: placing a lower completion assembly that includes a flow device to provide fluid communication between the lower completion assembly and a production zone associated with the lower completion assembly; placing an isolation assembly with a packer above the lower completion assembly for isolating an annulus between the lower completion assembly and the wellbore; placing a flow restriction device above the packer; setting the flow restriction device in the annulus to restrict flow of fluid through the annulus; and setting the packer after setting the flow restriction device.
A method of performing acoustic imaging includes: selecting a target location, and selecting a group of transducers from a plurality of transducers to transmit an acoustic beam to be electronically directed to the target location; selecting a transmitter having an orientation toward a location proximate to the target location, and transmitting an acoustic signal only by the transmitter; detecting an acoustic return signal by the transmitter and by a plurality of other transducers in the group; estimating a travel time for each of the group of transducers, the estimating including measuring a travel time for each of the other transducers, and estimating a travel time for the transmitter based on the travel time for each of the other transducers; and calculating beamforming delays based on the travel time, the beamforming delay configured to cause the group of transducers to direct an acoustic beam to the target location.
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
A flow control device having a longitudinal axis includes an outer housing having at least one fluid inlet, a multi-channel flow member positioned radially within the outer housing, a plurality of flow channels formed between the outer housing and the flow member, at least two of the plurality of flow channels having a different flow resistance rating from each other, and a radial window formed in an outlet region of each of the plurality of flow channels. The flow control device further includes a sliding sleeve positioned radially within the multi-channel flow member, the sliding sleeve including a first section of radial slots. The first section of radial slots is configured to align with a selected radial window via longitudinal movement of the sliding sleeve with respect to the multi-channel flow member.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/00 - Valve arrangements for boreholes or wells
60.
Completion assembly with bypass for reversing valve
An apparatus for use in a wellbore includes an outer assembly and inner assembly. The outer assembly includes a set down profile, a first flow device for supplying a fluid to a zone in the wellbore and a second flow device for providing a flow path from the formation to inside of the outer assembly. The inner assembly includes a frac port for supplying a fluid from the inner assembly to the first flow device, a valve below the frac port that remains closed when a fluid at a selected flow rate flows downward from above the valve, and a bypass device uphole of the valve. The bypass device opens when the inner assembly is set down in the set down profile and provides a flow path from below the frac port to an annulus between the inner assembly and the outer assembly above the frac port.
A method of recovering resources from a resource bearing formation includes selectively injecting a fluid into the resource bearing formation through one or more injector wells, extracting a resource from the resource bearing formation through one or more production wells, receiving at a sweep pattern controller, an input from each of the one or more production wells indicating an amount of the resource extracted over a period of time, determining, in the sweep pattern controller, an adjusted sweep pattern for the formation that substantially equalizes production from each of the one or more production wells, and signaling each of the one or more injector wells, from the sweep pattern controller, to selectively inject the fluid to establish the adjusted sweep pattern in the formation.
An opposed ramp assembly is configured with a load bearing lug. The lug has angled ends that match the opposed profile shapes that rotate as the lug reciprocates with each piston stroke. One side of the opposed profiles of the opposed ramp pattern has no axial travel grooves for the lug. On the other side there can be one or more open slots for the lug to facilitate assembly and disassembly of the lug to the operating location or to accommodate one or more needed positions for the tool depending on the application. As a result the opposed pattern peaks have increased spacing for the same stroke length of the piston. This allows for more reaction time in a partial stroke to avoid jamming because the potential position for jamming is far later so that reversal of movement can occur without jamming, if it occurs in the early part of the stroke. Peak to peak axial separation of the opposed pattern profiles is increased by a factor of at least 24.
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 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
63.
Packer plug with retractable latch, downhole system, and method of retracting packer plug from packer
A packer plug includes a retractable latch having at least one radially compressible finger having threads on an exterior surface, and a housing operatively arranged to move the at least one radially compressible finger inwardly during longitudinal movement of the housing in an uphole direction.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated 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
64.
Multi-beam phased array acoustic transducer operation for downhole applications
An apparatus for imaging a borehole wall includes an array of acoustic transducers and a controller. The controller scans a section of the borehole wall with first acoustic beams that are transmitted by a series of sets of acoustic transducers in the array to produce adjacent first acoustic measurements that are spaced a first distance D1 apart along the borehole wall, each set having at least one transducer that is different from an adjacent set, (ii) steers a second acoustic beam along the section of the borehole wall using one set of acoustic transducers in the array to produce adjacent second acoustic measurements that are a second distance D2 apart along the borehole wall, and (iii) images the borehole wall using the first acoustic measurements and the second acoustic measurement to generate a borehole wall image, wherein at least one second acoustic measurement is between adjacent first acoustic measurements.
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
G10K 11/34 - Sound-focusing or directing, e.g. scanning using electrical steering of transducer arrays, e.g. beam steering
G01S 15/89 - Sonar systems specially adapted for specific applications for mapping or imaging
G01S 7/52 - RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES - Details of systems according to groups , , of systems according to group
Actuation mechanisms for downhole assemblies in earth-boring applications may comprise a housing comprising an internal bore defining a flow path through the housing. An actuation member may be supported within the housing. A movable sleeve may be located within the internal bore and may be movable between a first position and a second position responsive to changes in flow rate of fluid flowing through the flow path. The movable sleeve may be biased toward the first position. The actuation member may be in an initial, pre-actuation position when the movable sleeve is initially located in the first position. The actuation member may be movable to a subsequent, pre-actuation position when the movable sleeve is located in the second position. The actuation member may be released from the actuation mechanism when the movable sleeve is returned to the first position.
E21B 41/00 - Equipment or details not covered by groups
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
66.
Actuation assemblies, hydraulically actuated tools for use in subterranean boreholes including actuation assemblies and related methods
Actuation assemblies include a valve assembly comprising a valve sleeve configured to rotate to selectively enable fluid flow through at least one aperture in the valve sleeve and into at least one port of an outer sleeve and a ball retention feature configured to selectively retain a ball dropped through a fluid passageway of the valve assembly in order to rotate the valve sleeve. Downhole tools include actuation assemblies. Methods for actuating a downhole tool include receiving a ball in an actuation assembly, rotating a valve sleeve of the actuation assembly to enable fluid to flow through a portion of the actuation assembly, and actuating a portion of the downhole tool with the fluid.
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
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 34/00 - Valve arrangements for boreholes or wells
67.
Expandable reamers and methods of using expandable reamers
Expandable reamers may include a housing and at least one blade supported by the housing. The at least one blade may be movable between an extended position and a retracted position. The at least one blade may be in the retracted position when a first actuation member is in a first longitudinal position and a second actuation member sleeve is affixed to the first actuation member. The at least one blade may be movable to the extended position when the first actuation member is in a second longitudinal position and the second actuation member is affixed to the first actuation member. The at least one blade may be in the retracted position when the first actuation member is in the second longitudinal position and the second actuation member obstructs an opening in a sidewall of the first actuation member.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
68.
Electrochemical sensor for monitoring under-deposit corrosion
An under-deposit corrosion (UDC) sensor includes a probe body with a curved concave probe surface that may have pre-deposited or in-situ formed thereon a material that accelerates the process of under deposit corrosion. The UDC sensor uses electrochemically-based localized monitoring techniques for assessing under-deposit pitting corrosion and the effectiveness of chemical treatment programs that mitigate under-deposit corrosion in well tubing, pipelines, vessels, and/or tanks.
A tool insertable into a wellbore for sampling formation fluids includes a body, and sample probe assemblies that project radially outward from the body and into sampling contact with the wellbore wall. Packers are provided on the outer terminal ends of the sample probe assemblies and which are urged against the wellbore wall. Actuator driven linkage assemblies selectively deploy and retract the packers from and back into the body. The sample probe assemblies are disposed at substantially the same axial location on the body, and are angularly spaced about an axis of the body. Each sample probe assembly is independently actuated, so that a discrete azimuthal portion can be sampled, and each has a dedicated sample container for storing sampled formation fluid.
An apparatus for interrogating a subsurface material includes a carrier configured to be conveyed through a borehole penetrating the earth, an array of acoustic transducers disposed on the carrier and configured to be compensated for ambient pressure in the borehole, and electronics coupled to the array and configured to operate the array to interrogate the subsurface material. Each acoustic transducer in the array includes a substrate, a bottom electrode disposed on the substrate, a top electrode disposed above the bottom electrode, an insulation layer disposed between the bottom electrode and the top electrode and defining a cavity into which the top electrode may deflect, and a pressure compensating fluid disposed in the cavity and in pressure communication with ambient pressure of the array.
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
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
B06B 1/02 - Processes or apparatus for generating mechanical vibrations of infrasonic, sonic or ultrasonic frequency making use of electrical energy
A fiber optic cable arrangement includes a core, a sheath surrounding the core and being strain locked to the core, and at least one optical fiber positioned within the sheath being strain locked to the core.
G02B 6/44 - Mechanical structures for providing tensile strength and external protection for fibres, e.g. optical transmission cables
G01L 1/24 - Measuring force or stress, in general by measuring variations of optical properties of material when it is stressed, e.g. by photoelastic stress analysis
72.
Flow-activated flow control device and method of using same in wellbore completion assemblies
A completion assembly for use in a wellbore is disclosed that in one non-limiting embodiment includes a tubular member having at least one packer to isolate a zone between the completion assembly and the wellbore, and a flow control device for closing flow of fluid through the tubular member, the flow control device including a valve that includes a fluid flow path and a seal member configured to close the fluid flow path, and a fluid-activated device that cycles each time a pressure differential is created across the flow path and moves the seal member to close the valve after completion of a selected number of cycles.
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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
A tubular occlusion and pressure damping system includes, a tubular, an occlusion configured to block flow through the tubular, the occlusion having, a first chamber in pressure communication with an inside of the tubular, a second chamber in fluidic communication with the first chamber, and a flow restrictor in operable communication with the first chamber and the second chamber. The flow restrictor configured to throttle flow between the first chamber and the second chamber such that pressure increases within the second chamber lag behind pressure increases in the inside of the tubular at least until the second chamber has reached a selected volume after which pressure within the second chamber increases toward the pressure in the inside of the tubular.
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
F16L 55/04 - Devices damping pulsations or vibrations in fluids
F16K 1/00 - Lift valves, i.e. cut-off apparatus with closure members having at least a component of their opening and closing motion perpendicular to the closing faces
An apparatus for performing a measurement of a downhole property includes an optical fiber having a first section that has a first set of fiber Bragg gratings with a first resonant wavelength inscribed therein and a second section that has a second set of fiber Bragg gratings with a second resonant wavelength different from the first resonant wavelength inscribed therein. The second section is in series with the first section. An optical interrogator emits a swept-wavelength frequency domain light signal having varying wavelength amplitude modulation into the optical fiber, receives a frequency domain return light signal, and transforms the frequency domain return signal into a time domain to determine a resonant wavelength shift of each fiber Bragg grating and the corresponding location of each interrogated fiber Bragg grating. A processor converts the resonant wavelength shift of each interrogated fiber Bragg grating into the downhole property measurement.
G01M 11/00 - Testing of optical apparatus; Testing structures by optical methods not otherwise provided for
G02B 6/12 - Light guides; Structural details of arrangements comprising light guides and other optical elements, e.g. couplings of the optical waveguide type of the integrated circuit kind
G01V 8/16 - Detecting, e.g. by using light barriers using one transmitter and one receiver using optical fibres
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
75.
Resonator assembly limiting magnetic particle accumulation from well fluids
Systems, devices and methods for determining a parameter of interest of a well fluid relating to a well intersecting a subterranean formation using resonant vibration. The apparatus may include a resonator assembly. The resonator assembly may comprise a plurality of resonant tines structurally coupled to behave as a single resonator. At least one resonant tine of the plurality of resonant tines may include a soft magnetic tine head comprising soft magnetic material uncontained by a supporting surface. Each corresponding tine of the plurality of resonant tines may be formed by at least the resonant tine head and a tine shaft. Each corresponding tine may have a cross section perpendicular to a longitudinal axis of the corresponding tine, the cross section including a tine head, where the cross section has a substantially continuous material composition. Each tine shaft may terminate at the tine head.
A filtering assembly is laid flat on an outer shroud. An inner drainage layer is set over the filtering assembly while laid flat such that the inner drainage layer overlaps the filtering assembly. The inner drainage layer is sealed and secured to the outer shroud by diffusion bonding or welding while overlaying the filtering assembly. With the filtering assembly held firm between the inner drainage layer and the outer shroud a spiral winding procedure is commenced to roll the flat assembly into a cylindrical shape. The edges are sealed by welding or diffusion bonding. The spiral winding and seam closure can be done on a perforated base pipe or the base pipe can be inserted into the finished assembly at a later time and secured. Alternatively the filtering assembly and outer shroud, with or without the drainage layer can be wound over a perforated base pipe or a complete screen assembly.
B23K 31/02 - Processes relevant to this subclass, specially adapted for particular articles or purposes, but not covered by any single one of main groups relating to soldering or welding
B23K 20/02 - Non-electric welding by applying impact or other pressure, with or without the application of heat, e.g. cladding or plating by means of a press
B01D 29/11 - Filters with filtering elements stationary during filtration, e.g. pressure or suction filters, not covered by groups ; Filtering elements therefor with bag, cage, hose, tube, sleeve or like filtering elements
B01D 35/02 - Filters adapted for location in special places, e.g. pipe-lines, pumps, stop-cocks
A method of installing multi-trip completions in a borehole. The method includes interfacing a health monitoring system with a first section of the multi-trip completions, the health monitoring system configured to engage with at least one of a first control line and first equipment of the first section. Running the health monitoring system and the first section downhole to a selected position within the borehole; storing information about a health of the at least one of the first control line and first equipment of the first section within the health monitoring system. Removing the health monitoring system from the borehole while leaving the first section within the borehole; accessing the information from the health monitoring system; and, determining, based on the information, whether or not to run a second section having a second control line into the borehole. The second control line configured to connect with the first control line.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A system for communicating with subsurface components includes: a surface host connected to a subsurface location; a subsurface host connected to the surface host by a communication link, the subsurface host configured to communicate with the surface host using a communication protocol; and a plurality of tools configured to be disposed in a borehole, the plurality of downhole tools communicatively coupled to the subsurface host via a communication network. The communication network is divided into a plurality of network subsets, each network subset of the plurality of network subsets including one or more downhole tools, all of the one or more downhole tools configured to communicate using a common protocol, each network subset including a network device configured to receive data and translate the data to the common protocol, the common protocol of one network subset being different than the common protocol of at least one other network subset.
G01V 3/00 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation
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
H04L 29/08 - Transmission control procedure, e.g. data link level control procedure
H04L 29/06 - Communication control; Communication processing characterised by a protocol
79.
Displacement measurements using simulated multi-wavelength light sources
An embodiment of an apparatus for estimating a parameter includes a multi-wavelength electromagnetic source configured to emit electromagnetic radiation beams having multiple wavelengths at a fixed angle relative to an interferometer, the multi-wavelength source having a stabilizer configured to lock each beam to one of a plurality of discrete wavelength ranges. The apparatus also includes the interferometer, which has a fixed reference reflector and a moveable reflecting assembly coupled to a moveable mass, the mass configured to move in response to the parameter. The apparatus further includes a detector configured to detect an interference pattern generated by the interferometer for each beam, and a processor configured to combine the interference patterns and estimate the parameter based on the combined interference pattern.
G01L 1/24 - Measuring force or stress, in general by measuring variations of optical properties of material when it is stressed, e.g. by photoelastic stress analysis
G01V 7/00 - Measuring gravitational fields or waves; Gravimetric prospecting or detecting
G01V 1/16 - Receiving elements for seismic signals; Arrangements or adaptations of receiving elements
G01V 8/12 - Detecting, e.g. by using light barriers using one transmitter and one receiver
80.
Guided acoustic waves isolation system for downhole applications
An apparatus for estimating a property of a subsurface material includes a carrier configured to convey an acoustic wave guide though a borehole. The acoustic wave guide includes an acoustic plate configured to guide an acoustic wave along a path of the plate and an acoustic reservoir coupled to the acoustic plate and at least partially surrounding the acoustic plate. The acoustic reservoir has a mass greater than the mass of the acoustic plate and is configured to absorb acoustic wave leakage from the acoustic plate. A first acoustic transducer is coupled to the acoustic plate and configured to transmit an acoustic wave along the path. A second acoustic transducer is coupled to the acoustic plate and configured to receive the acoustic wave that travels along the path. A controller is configured to operate the first acoustic transducer and the second acoustic transducer in order to estimate the property.
A cutting element for an earth-boring tool includes a substrate and volume of superabrasive material positioned on the substrate. The volume of superabrasive material includes a cutting face having at least one recess extending into the volume of superabrasive material and/or at least one protrusion extending outward from the volume of superabrasive material. The volume of superabrasive material includes a first chamfer surface having a peripheral edge and a radially innermost edge. The peripheral edge of the first chamfer surface is located proximate a cutting edge of the volume of superabrasive material. A radial width of the first chamfer surface is between about 0.002 inch and about 0.045 inch. The volume of superabrasive material also includes a second chamfer surface having a peripheral edge and a radially innermost edge. The peripheral edge of the second chamfer surface is located adjacent the radially innermost edge of the first chamfer surface.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
B24D 99/00 - Subject matter not provided for in other groups of this subclass
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
An embodiment of a method of manufacturing a downhole fluid control apparatus includes generating, using a processor, a design for a metallic porous structure configured to be deployed with a fluid control device, the fluid control device configured to be disposed in a borehole in an earth formation and inhibit the flow of particulates between a flow conduit and at least one of the borehole and the formation. The method also includes applying an energy beam from an energy source to a granular metallic material, and additively forming the metallic porous structure based on the design as a single structure having a distribution of pores therein.
Systems and methods for communicating messages over a three-phase power cable between surface equipment and downhole equipment in a well. A transmitter parses messages into data bit pairs and generates a parity bit for each pair (a triplet). The bits of each triplet are concurrently but separately transmitted over the power cable. Each triplet is received from the power cable by a receiver and is decoded to identify the data bits. The receiver may verify the received bits and/or recover a lost bit in each triplet. The data bits are then reconstructed into the original message. Since each triplet has two bits, the effective data rate is twice the data rate of transmitting a single bit at a time. The parity bit enables recovery of data with a bit error rate of up to 1 in 3.
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
F04B 47/00 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
Activation modules for selectively sealing entrances to inner barrels of coring tools may include an activator body sized and configured to obstruct the entrance to the inner barrel when the activation module is in a first state and to release the entrance to the inner barrel when the activation module is in a second state. A sealing element may be located at a periphery of the activator body, and may be configured to form a seal between at least a portion of an interior of the inner barrel and at least a portion of an exterior of the inner barrel when the activation module is in the first state and to disengage the seal when the activation module is in the second state.
E21B 33/10 - Sealing or packing boreholes or wells in the borehole
E21B 25/10 - Formed core retaining or severing means
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
S of at least about 5 dB/cm when subjected to an acoustic signal at a frequency between about 200 to 500 kHz. The acoustic interface device may be formed of polytetrafluoroethylene (Teflon®), a perfluoroalkoxy alkane (PFA), polycarbonate (Lexan®), or polyether ether ketone (PEEK). Methods of using the acoustic interface device with a transducer for ultrasonic measurement of a specimen are also disclosed.
G01N 29/00 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object
G01D 5/12 - Mechanical means for transferring the output of a sensing member; Means 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 converting; Transducers not specially adapted for a specific variable using electric or magnetic means
G01N 29/28 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object - Details providing acoustic coupling
86.
Failsafe control system for a safety valve having a condition sensing and chemical injection feature
A control system for a Subsurface Safety Valve (SSSV), includes an actuating piston mounted in a housing with at least one seal and connected to the SSSV. The actuating piston having a first end and a second end, the first end in fluid communication with a control line; a primary pressure reservoir in fluid communication with the second end of the actuating piston, the reservoir configured to contain a fluid under an amount of pressure selected to act against a prospective hydrostatic pressure expected in the control line based upon the selected position of the control system in a downhole environment. An equalizing piston in fluid communication with both the control line and with the second end of the actuating piston, the equalizing piston remaining in a closed position during shifting of the actuating piston with pressure applied or removed from the control line, the equalizing piston movable to an open position upon a control system failure that reduces pressure in the primary reservoir to below a threshold value; and a condition sensing and chemical injection assembly in fluid communication with the primary reservoir. A method for operating a control system for a Subsurface Safety Valve (SSSV).
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 34/06 - Valve arrangements for boreholes or wells in wells
87.
Drive off method from subsea well with pipe retention capability
This invention involves a method of securing pipe (also referred to as a “string of tools”) when driving off a subsea well or sealing off a well in onshore applications where there is an emergency by grabbing the pipe before it is cut. A pipe ram then is closed on the pipe before a shear ram is actuated to cut the pipe. In subsea applications, the top of the pipe may then be raised clear of the blowout preventer within a marine riser. A blind ram and annular preventer can then be closed above the remnant of the pipe being retained by the pipe catcher. The pipe above the cut is removed through the marine riser and the marine riser itself is then disconnected. The rig is then driven off the well. If the well is reactivated the steps are reversed but the well is safely secured before the blowout preventer components are opened. The pipe supported by the catcher is independently supported before the catcher is released and the pipe lifted through the riser.
E21B 29/12 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground specially adapted for underwater installations
E21B 33/064 - Blow-out preventers specially adapted for underwater well heads
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
E21B 33/076 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
Opposed cones for slips on a packer have an annular undercut in general alignment with the end of the cone that has the slip ramp. The undercut faces the mandrel on which the cones can be driven together to radially extend the slips. A high modulus insert sleeve is interference fitted to the undercut. This results in the cone exterior surface being in hoop stress tension before the slips are set. Once the slips are set and a reaction load comes radially back from the surrounding tubular into which the slips have extended there is a tendency for the reaction force to put the exterior surface of the cones into compressive hoop stress. The initial tensile hoop stress from the sleeve placement acts to at least in part offset the reaction force tending to create compressive hoop stress. The net loading and deflection of the mandrel is minimized.
In one aspect, a pressure differential device including: an inlet; an outlet; and a fluid restricting member fluidly associated with the inlet and the outlet, wherein the fluid restricting member is configured to provide a first backpressure at a first setting and a second plurality of backpressures at a plurality of second settings. In another aspect, a method to control backpressure including: providing a fluid line with an inlet fluid flow; supplying the inlet fluid flow into a pressure differential device; expelling an outlet fluid flow out of the pressure differential device; pressurizing the inlet fluid flow to a first backpressure at a first setting of the pressure differential device; pressurizing the inlet fluid flow to a second plurality of backpressures at a plurality of second settings of the pressure differential device.
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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
F16K 31/53 - Mechanical actuating means with toothed gearing
F16K 31/54 - Mechanical actuating means with toothed gearing with pinion and rack
F16K 17/06 - Safety valves; Equalising valves closing on insufficient pressure on one side spring-loaded with special arrangements for adjusting the opening pressure
90.
Self-boosting expandable seal with cantilevered seal arm
A downhole seal assembly includes a body extending from an uphole end to a downhole end. The body includes a first sealing surface and an opposing, second sealing surface that is angled relative to the first sealing surface. A first void is formed in the second sealing surface adjacent the uphole end, and a seal is arranged in the first void. A second void is formed in the second sealing surface adjacent the downhole end. One or more passages is formed in the downhole end and fluidically coupled to the second void. The one or more passages is configured and disposed to guide downhole fluids into the second void forcing the first sealing surface against a wellbore.
An apparatus for estimating gravitational properties includes an optical source, a first interferometer including a fixed reference reflector and a first reflector coupled to a first moveable mass, a second interferometer including the fixed reference reflector and a second reflector coupled to a second moveable mass, a first detector configured to detect a first interference pattern generated by the first interferometer, and a second detector configured to detect a second interference pattern generated by the second interferometer. The first mass is configured to move a first amount in response to a change in gravitational force, and the second mass is configured to move a second amount in response to a change in gravitational force, the second amount being smaller than the first amount. The apparatus also includes a processor configured to estimate the change in gravitational force based on a combination of the first and second interference patterns.
A downhole communication and control system configured for use in a non-sequential order of treating a borehole, the system includes a string having at least three ports including first, second, and third longitudinally spaced ports arranged sequentially in a downhole to uphole manner in the string; at least three frac sleeve systems including first, second, and third frac sleeve systems arranged sequentially in a downhole to uphole manner in the string and arranged to open and close the first, second, and third ports, respectively, each frac sleeve system having self-powered, electronically triggered first and second sleeves; and, communication signals to trigger the first, second, and third frac sleeve systems into moving the first and second sleeves to open and close the ports. Also included is a method of completing downhole operations in a non-sequential order.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
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 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
Methods, systems, and devices for determining a parameter of interest of downhole fluid using an acoustic assembly comprising a single solid acoustic transmission medium having a face immersed in the downhole fluid. Methods include using characteristics of a plurality of acoustic pulse reflections from a solid-liquid interface at the face of the solid acoustic transmission medium to estimate the parameter of interest in near real-time. The characteristics may comprise a corresponding reflection amplitude and the corresponding unique angle of reflection for each acoustic pulse reflection. Methods may include generating a two dimensional data set from measured characteristics, generating a curve by performing data fitting on the two dimensional data set, and using the reciprocal slope of the curve to estimate the parameter of interest. Methods may include estimating time-dependent values for the parameter of interest substantially continuously while the acoustic assembly is on a single logging run in the borehole.
G01H 5/00 - Measuring propagation velocity of ultrasonic, sonic or infrasonic waves
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
94.
Completion tool, string completion system, and method of completing a well
A completion system includes, a tool string having, a plurality of packers configured to isolate a plurality of zones along a borehole that the tool string is positioned within. A plurality of ports along the tool string are configured to be selectively opened and a plurality of screens in operable communication with the plurality of ports are configured to filter fluid flowing between the zones and an inside of the tool string through the plurality of ports. The tool string is also configured to be run into the borehole, the plurality of packers set, the plurality of ports selectively opened, and fluid to flow between the plurality of zones and an inside of the tool string without intervention.
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 33/124 - Units with longitudinally-spaced plugs for isolating the intermediate space
E21B 33/128 - Packers; Plugs with a member expanded radially by axial 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
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
Coring tools configured to procure core samples of earth formations may include a coring bit comprising a cutting structure configured to cut a core sample and an outer barrel connected to the coring bit. The outer barrel may be configured to apply axial and rotational force to the coring bit. An inner barrel may be located within the outer barrel and may be configured to receive a core sample within the inner barrel. A sponge material may line an inner surface of the inner barrel and may be configured to absorb a fluid from the core sample. A stabilizer may be connected to the outer barrel. At least one blade of the stabilizer may be rotatable with respect to the outer barrel and may be configured to remain at least substantially rotationally stationary relative to the earth formation during coring.
A landing collar includes a tubular body having a longitudinally extending main flow path; and, a shearable liner wiper plug landing seat installed within the body and configured to receive a liner wiper plug in an unsheared condition of the landing seat. The landing seat movable in a downhole direction within the body in a sheared condition of the landing seat. The landing seat including at least one radial fluid communication passageway through a wall of the landing seat; wherein, in the sheared condition of the landing seat. The fluid communication passageway of the landing seat is in fluid communication with a fluid communication path between the tubular body and the landing seat. A method of completing a cemented liner with a wet shoe.
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
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 43/10 - Setting of casings, screens or liners in wells
97.
Penetrator for a puncture communication tool and method
A penetrator for a Puncture Communication Tool includes a base; a body extending from the base and terminating at a tip; and a fluid bypass disposed in the body. Communicating a hydraulic chamber.
E21B 34/00 - Valve arrangements for boreholes or wells
E21B 41/00 - Equipment or details not covered by groups
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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
A gravel pack system includes a tool string having an inner string member, an outer string member, and a passage arranged between the outer string member and the inner string member. A packing element is provided on the outer string member. A first valve is coupled to one of the outer string member and the inner string member outwardly of the packing element in a downhole direction. The first valve fluidically connects the passage and the open hole wellbore. The first valve is configured and disposed to shift from a closed position to an open position. A second valve is coupled to one of the outer string member and the inner string member outwardly of the packing element in an uphole direction. The second valve selectively fluidically connects the passage and the open hole wellbore. The second valve shifts from an open position to a closed position.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 33/124 - Units with longitudinally-spaced plugs for isolating the intermediate space
A vibration detector and method of measuring vibration are described. The vibration detector includes an optical fiber comprising a reference reflector and a delay coil, and one or more sensors comprised at respective one or more locations in the optical fiber, each of the one or more sensors including a center reflector and two side reflectors on either side of the center reflector, the delay coil eliminating detection of interference among reflections from the one or more sensors. The vibration detector also includes a light source to introduce light into the optical fiber to interrogate the optical fiber, a detector to obtain interference signals, each of the interference signals being based on interference between reflections from the reference reflector and one of the one or more sensors; and a processor to process each of the interference signals to obtain vibration measurements.
A method of completing a well includes, pumping treating fluid into a tool string in the well, displacing drilling mud within the tool string with the treating fluid, and treating an earth formation with the treating fluid.
G01V 3/08 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 34/00 - Valve arrangements for boreholes or wells
patents
