Non-acidic sulfur compounds (e.g., thiols) can be selectively extracted from a hydrocarbon stream containing them (e.g., crude oil) by contacting the hydrocarbon stream with a carbonate solvent that contains at least one organic carbonate (e.g., propylene carbonate) in an amount effective to selectively absorb and extract the non-acidic sulfur compounds therefrom. The carbonate solvent may optionally also comprise an additional solvent (e.g., caprolactam), a soluble metal salt (e.g., a metal salt where the metal is iron), and/or a mercaptan scavenger that is a heterocyclic amine (e.g., oxazolidine).
C10G 21/02 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents with two or more solvents, which are introduced or withdrawn separately
2.
Side Pocket Mandrel Promoting High Internal Velocity
A side pocket mandrel for use in a gas lift system is configured to improve the recovery of petroleum fluids from a well. The side pocket mandrel includes an upper assembly joint, a lower assembly joint, and a central portion that has a total length (LT). The side pocket mandrel further comprises a central bore extending through the side pocket mandrel along a central longitudinal axis that extends through the upper and lower assembly joints. The side pocket mandrel further includes a tool channel offset from the central bore and a side pocket tube linearly aligned with the tool channel and configured to receive a gas lift valve. The side pocket mandrel further includes a pair of primary flow blocks that each have a length (LFa) that is at least 35% of the total length (LT) of the central portion of the side pocket mandrel.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
3.
ANOMALY DETECTION IN ADDITIVE MANUFACTURING USING MELTPOOL MONITORING, AND RELATED DEVICES AND SYSTEMS
Methods for anomaly detection in additive manufacture using meltpool monitoring are disclosed. A method includes obtaining a process model representative of an object to be generated through additive manufacture. The method also includes generating, based on the process model and using a hybrid machine-learning model, an instruction for generating the object through additive manufacture. Another method includes generating a layer of an object, and taking a reading relative to the generation of the layer. The other method also includes updating, based on the reading and using a hybrid machine-learning model, a process model, the process model representative of the object. The other method also includes generating, based on the updated process model and using the hybrid machine-learning model, an instruction for generating a subsequent layer of the object through additive manufacture. Related systems and devices are also disclosed.
A perforation and fracture tool including a perforating gun, a cone mandrel operatively connected to the gun, a slip operatively connected to the cone mandrel, and a seal element between the gun and the slip. A method for perforating and fracturing including initiating a perforation gun, driving a cone mandrel with evolved gas from the initiation, setting a seal, and pressuring against the seal to a fracture pressure. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a perforation and fracture tool disposed within or as a part of the string.
In one aspect, embodiments of the present disclosure are directed to a process for manufacturing a side pocket mandrel that involves welding upper and lower swages to a central body of the side pocket mandrel. In some embodiments, the process includes the steps of providing a first side of the welded joint and a second side of the welded joint, where the first and second sides are either the central body or the swage. The process continues with the step of approximating the first and second sides such that the first and second sides are in contact. Importantly, the first and second sides are brought together without creating a root gap between the first and second sides. Next, the first and second sides are welded together to form the welded joint between the swage and the central body.
In at least one embodiment, a well inspection method (600) and system (500) is disclosed. The method (600) includes transmitting (602) an acoustic signal from a well inspection tool into a casing structure, receiving (604) return signals from the casing structure to the well inspection tool, performing (606), using at least one processor associated with the well inspection tool, a Fast Fourier Transform (FFT) on a plurality of frequencies of the return signals to generate spectrogram data, determining (610) entropy spectra from the spectrogram data, and determining (612) casing loadings associated with the casing structure based at least in part on the entropy spectra.
A method for attaching a ring to a borehole tool including locating the ring on the tool, running a weld bead around the ring without alloying the ring to another parent material, the weld causing contraction in a circumferential dimension of the ring. A method for producing a ring for a downhole tool including forming the ring with a weld groove at an outside surface of the ring. A ring for a downhole tool including a ring body, a weld groove formed in an outside surface of the ring. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a ring disposed on the string.
A side pocket mandrel (118) for use in a gas lift system (100) is configured to improve the recovery of petroleum fluids from a well (102). The side pocket mandrel (118) includes an upper assembly joint (120), a lower assembly joint (122), and a central portion (124) that has a total length (LT). The side pocket mandrel (118) further comprises a central bore (128) extending through the side pocket mandrel (118) along a central longitudinal axis that extends through the upper and lower assembly joint (122)s. The side pocket mandrel (118) further includes a tool channel (138) offset from the central bore (128) and a side pocket tube (126) linearly aligned with the tool channel (138) and configured to receive a gas lift valve. The side pocket mandrel (118) further includes a pair of primary flow blocks (136) that each have a length (Lpa) that is at least 35% of the total length (LT) of the central portion (124) of the side pocket mandrel (US).
A submersible pumping system for producing a fluid from a wellbore through production tubing to a wellhead includes a motor controlled by a motor drive, a pump driven by the motor, and one or more downhole sensors configured to measure conditions at the motor and pump. An intake fluid density control system has a control fluid reservoir positioned above the pump that is configured to release a density7 control fluid to the intake of the pump under the force of gravity. The release of the density control fluid can be controlled by a dump valve that automatically moves between open, closed, and intermediate positions in response to a control signal based on measurements made by the downhole sensors or motor drive.
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
In one aspect, embodiments of the present disclosure are directed to a process for manufacturing a side pocket mandrel that involves welding upper and lower swages to a central body of the side pocket mandrel. In some embodiments, the process includes the steps of providing a first side of the welded joint and a second side of the welded joint, where the first and second sides are either the central body or the swage. The process continues with the step of approximating the first and second sides such that the first and second sides are in contact. Importantly, the first and second sides are brought together without creating a root gap between the first and second sides. Next, the first and second sides are welded together to form the welded joint between the swage and the central body.
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
11.
OPTICAL SYSTEM AND METHOD FOR CLEANING OPTICAL WINDOWS
A system for downhole optical analysis includes a housing forming at least part of a pressure barrier. The system also includes a window, formed at an end of the housing, the window being at least semi-transparent to permit light to travel through the window. The system further includes at least one light source, arranged within the housing, wherein the at least one light source is configured to emit a beam of light at a wavelength to enable non-contact, optical cleaning of the window, the wavelength being selected to reduce interaction with the window while heating a fluid film formed on the window outside the housing.
A valve including a flexible tube having two ends, a first structure disposed at one of the two ends and rotationally anchored thereto, and a second structure at the other of the two ends and rotationally anchored thereto, at least one of the first and second structures being rotatable relative to the other of the first and second structures. A method for controlling a flow of fluid including rotating one of the first structure and second structure relative to the other of the first structure and second structure of the valve reducing a dimension of a flow path within a flexible tube. A borehole system including a borehole in a subsurface formation, and a valve disposed in the borehole.
A seal including a seal material and a temperature control material in thermal communication with the seal material. A method for producing a seal having temperature regulating properties including adding a dopant to a seal material in a quantity that supports electrical conductivity and disposing an electrical connector on the seal. A borehole system comprising a borehole in a subsurface formation, a string in the borehole, and a seal tool disposed within or as a part of the string.
A seal includes a seal body and a temperature controller in thermal communication with the seal material. A method for controlling temperature of a seal including applying an energy source to the temperature controller, and generating a temperature difference in the temperature controller. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a seal tool disposed within or as part of the string.
In at least one embodiment, a well inspection method and system is disclosed. The method includes transmitting an acoustic signal from a well inspection tool into a casing structure, receiving return signals from the casing structure to the well inspection tool, performing, using at least one processor associated with the well inspection tool, a Fast Fourier Transform (FFT) on a plurality of frequencies of the return signals to generate spectrogram data, determining entropy spectra from the spectrogram data, and determining casing loadings associated with the casing structure based at least in part on the entropy spectra.
A valve including a flexible tube having two ends, a first structure disposed at one of the two ends and rotationally anchored thereto, and a second structure at the other of the two ends and rotationally anchored thereto, at least one of the first and second structures being rotatable relative to the other of the first and second structures. A method for controlling a flow of fluid including rotating one of the first structure and second structure relative to the other of the first structure and second structure of the valve reducing a dimension of a flow path within a flexible tube. A borehole system including a borehole in a subsurface formation, and a valve disposed in the borehole.
A seal including a seal material and a temperature control material in thermal communication with the seal material. A method for producing a seal having temperature regulating properties including adding a dopant to a seal material in a quantity that supports electrical conductivity and disposing an electrical connector on the seal. A borehole system comprising a borehole in a subsurface formation, a string in the borehole, and a seal tool disposed within or as a part of the string.
A method for improving sealing in boreholes includes temperature controlling seals to maintain sealing loading by managing temperature of the seal to a target temperature range. A borehole system includes a borehole in a subsurface formation, a string in the borehole, a seal tool in contact with the string and temperature controller within or in thermal proximity to the seal.
A downhole tool including a gravel pack assembly, a remotely addressable actuator connected to the gravel pack assembly, and a valve responsive to the actuator, the valve opening and closing a washdown path through the tool. A method for gravel packing a borehole including running a tool to a target depth in the borehole, flowing washdown fluid through the tool, sending an electric signal to the actuator to close the valve, and flowing through a cross over port of the gravel pack assembly. A borehole system including a borehole in a subsurface formation, a tool disposed within the borehole.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A method for attaching a ring to a borehole tool including locating the ring on the tool, running a weld bead around the ring without alloying the ring to another parent material, the weld causing contraction in a circumferential dimension of the ring. A method for producing a ring for a downhole tool including forming the ring with a weld groove at an outside surface of the ring. A ring for a downhole tool including a ring body, a weld groove formed in an outside surface of the ring. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a ring disposed on the string.
A submersible pumping system for producing a fluid from a wellbore through production tubing to a wellhead includes a motor controlled by a motor drive, a pump driven by the motor, and one or more downhole sensors configured to measure conditions at the motor and pump. An intake fluid density control system has a control fluid reservoir positioned above the pump that is configured to release a density control fluid to the intake of the pump under the force of gravity. The release of the density control fluid can be controlled by a dump valve that automatically moves between open, closed, and intermediate positions in response to a control signal based on measurements made by the downhole sensors or motor drive.
A method for improving sealing in boreholes includes temperature controlling seals to maintain sealing loading by managing temperature of the seal to a target temperature range. A borehole system includes a borehole in a subsurface formation, a string in the borehole, a seal tool in contact with the string and temperature controller within or in thermal proximity to the seal.
An electrical submersible pumping system (“ESP”) for use in a wellbore includes an electrical motor, a pump, a shaft coupled between the motor and pump, and a lubricant pump for circulating lubricant within the ESP. The lubricant pump includes a diffuser and an impeller that mounts onto and rotates with shaft rotation. A portion of the impeller has a frusto-conical outer surface, which is circumscribed by a portion of the diffuser profiled complementary to the frusto-conical portion of the impeller. The pump directs lubricant flow in a single direction irrespective of the rotational direction of the shaft.
A downhole tool including a gravel pack assembly, a remotely addressable actuator connected to the gravel pack assembly, and a valve responsive to the actuator, the valve opening and closing a washdown path through the tool. A method for gravel packing a borehole including running a tool to a target depth in the borehole, flowing washdown fluid through the tool, sending an electric signal to the actuator to close the valve, and flowing through a cross over port of the gravel pack assembly. A borehole system including a borehole in a subsurface formation, a tool disposed within the borehole.
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
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
25.
BOREHOLE SEALING WITH TEMPERATURE CONTROL, METHOD, AND SYSTEM
A seal includes a seal body and a temperature controller in thermal communication with the seal material. A method for controlling temperature of a seal including applying an energy source to the temperature controller, and generating a temperature difference in the temperature controller. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a seal tool disposed within or as part of the string.
An electrical submersible pumping system ("ESP") for use in a wellbore includes an electrical motor, a pump, a shaft coupled between the motor and pump, and a lubricant pump for circulating lubricant within the ESP. The lubricant pump includes a diffuser and tin impeller that mounts onto and rotates with shaft rotation. A portion of the impeller has a frusto-conical outer surface, which is circumscribed by a portion of the diffuser profiled complementary to the frusto-conical portion of the impeller. The pump directs lubricant flow in a single direction irrespective of the rotational direction of the shaft.
A submersible pumping system is designed to handle the production of two-phase fluids from a subterranean well. In some embodiments, the pumping systems include a combination of elements that are configured to separate gas from the two-phase fluid and provide a recirculated stream of liquid-dominant fluid to the intake of the pumping system. The pumping system includes a gas handler pump, a production pump and a liquid separator. In some embodiments, the pumping system also includes a gas separator. In other embodiments, the pumping system is encapsulated such that the motor, gas handler pump, production pump and liquid separator are contained within a common capsule. The disclosed pumping systems can be configured for onshore or offshore applications.
E21B 43/38 - Arrangements for separating materials produced by the well in the well
E21B 43/40 - Separation associated with re-injection of separated materials
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
A process of manufacturing an electrode includes: adding an electrode active material and an additive to a mixer to form an electrode composition, the additive comprising at least one of a binder or a conductive agent; depositing the electrode composition on a substrate to form a first electrode layer; varying the electrode composition by changing a relative amount of the electrode active material and the additive added to the mixer, changing a composition of the electrode active material added to the mixer, changing a composition of the additive added to the mixer, or a combination thereof to form a plurality of additional adjusted electrode compositions; depositing the plurality of the additional adjusted electrode compositions on the first electrode layer to additively form the electrode such that a concentration of the electrode active material, a concentration of the additive, the composition of the electrode active material, the composition of the additive, or a combination thereof vary from the substrate to an exposed surface of the electrode.
B01F 23/53 - Mixing liquids with solids using driven stirrers
B01F 27/724 - Mixers with rotary stirring devices in fixed receptacles; Kneaders with stirrers rotating about a horizontal or inclined axis with helices or sections of helices with a single helix closely surrounded by a casing
B05D 1/26 - Processes for applying liquids or other fluent materials performed by applying the liquid or other fluent material from an outlet device in contact with, or almost in contact with, the surface
G05D 11/13 - Controlling ratio of two or more flows of fluid or fluent material characterised by the use of electric means
H01M 4/1391 - Processes of manufacture of electrodes based on mixed oxides or hydroxides, or on mixtures of oxides or hydroxides, e.g. LiCoOx
H01M 4/1393 - Processes of manufacture of electrodes based on carbonaceous material, e.g. graphite-intercalation compounds or CFx
H01M 4/1395 - Processes of manufacture of electrodes based on metals, Si or alloys
H01M 4/1397 - Processes of manufacture of electrodes based on inorganic compounds other than oxides or hydroxides, e.g. sulfides, selenides, tellurides, halogenides or LiCoFy
In some implementations, a method includes receiving data characterizing a plurality of acoustic signals detected at a plurality of segments of an industrial system. A first data subset of the received data is associated with a first acoustic signal detected at a first segment of the plurality of segments and a second data subset of the received data is associated with a second acoustic signal detected at a second segment of the plurality of segments. The method also includes a first characteristic color to the first data subset based on a first time of propagation and an amplitude of the first acoustic signal, and assigning a second characteristic color to the second data subset based on a second time of propagation and amplitude of the second acoustic signal.
A solid oxide fuel cell includes an anode, a cathode, an electrolyte including zirconia between the anode and the cathode, and at least one current collector on a surface of the anode opposite the electrolyte and/or a surface of the cathode opposite the electrolyte. The at least one current collector may include a material of Mn+1AXn composition, wherein M is an early transition metal, A is a Group IIIA element or a Group IVA element, X is carbon (C) or nitrogen (N), and n is an integer from 1 to 3. Related methods and systems are also disclosed.
H01M 8/0217 - Complex oxides, optionally doped, of the type AMO3, A being an alkaline earth metal or rare earth metal and M being a metal, e.g. perovskites
B33Y 80/00 - Products made by additive manufacturing
H01M 4/86 - Inert electrodes with catalytic activity, e.g. for fuel cells
H01M 8/1253 - Fuel cells with solid electrolytes operating at high temperature, e.g. with stabilised ZrO2 electrolyte characterised by the process of manufacturing or by the material of the electrolyte the electrolyte consisting of oxides the electrolyte containing zirconium oxide
H01M 8/2425 - High-temperature cells with solid electrolytes
32.
METHOD TO TREAT AND MINIMIZE SLUDGE FROM BIOREFINERIES
It is a continuing goal to reduce the amount of sludge produced in a biorefinery while also improving oil quality and water quality. In one aspect, an exemplary method of minimizing sludge from biorefineries includes the steps of feeding a source feedstock into a degumming centrifuge, where the source feedstock is separated into wet oil and a primary sludge stream, and conveying a portion of the primary sludge stream to a three-phase centrifuge. At the three-phase centrifuge, the portion of the primary sludge stream is separated into recovered centrifuge oil, which is retrieved; centrifuged water, which is conveyed to a wastewater treatment plant; and centrifuged sludge. The remainder of the primary sludge stream is conveyed to a gravity separator, where the remainder of the primary sludge stream is separated into recovered oil and residual sludge. The residual oil is retrieved from the gravity separator.
The present disclosure is for an inverted diffuser usable in wellheads and other wellsite equipment. The inverted diffuser includes at least one first section having a first vertical inner surface, a first inclined inner surface relative to the first vertical inner surface, and one or more channels supporting one or more releasable fasteners between the at least one first section and a wall of a wellhead or of a wellsite equipment. At least one second section is press-fitted or fastened adjacent to the at least one first section. A method for application of the inverted diffuser in a wellhead and in other wellsite equipment is also disclosed, along with a method of manufacture of the inverted diffuser.
A wellbore system includes an upper head and a lower head coupled to the upper head by one or more fasteners. The wellbore system also includes a seal ring positioned within a seal pocket to engage the upper head to form a first seal interface between the upper head and the seal ring. The wellbore system includes a hanger arranged within a bore. The wellbore system includes a packoff positioned between the hanger and the lower head. The wellbore system includes one or more lock screws to apply a downward force to the packoff to establish a second seal interface between the packoff and the seal ring and a third seal interface between the packoff and the hanger.
An earth-boring tool system may include a drill string, and at least one or more sensors. The earth-boring tool system may receive data indicative of wear of at least part of a drilling tool, obtain labeled dull grading data for the drilling tool based on the received data, obtain a physics-based bit wear model based on one or more drilling parameters, generate one or more physics-based dull grading data labels based on the physics-based bit wear model, and train an artificial intelligence bit wear model based on the labeled dull grading data and the physics-based dull grading labels.
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
A pressure sensor including a crystal housing, a transducer crystal disposed in the housing in vacuum conditions, a driver in contact with the crystal transducer, and a deflectable member in contact with the driver on one surface and exposed to ambient pressure on the opposite surface thereof. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a sensor connected to the string.
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
It is a continuing goal to reduce the amount of sludge produced in a biorefinery while also improving oil quality and water quality. In one aspect, an exemplary method of minimizing sludge from biorefineries includes the steps of feeding a source feedstock into a degumming centrifuge, where the source feedstock is separated into wet oil and a primary sludge stream, and conveying a portion of the primary sludge stream to a three-phase centrifuge. At the three-phase centrifuge, the portion of the primary sludge stream is separated into recovered centrifuge oil, which is retrieved; centrifuged water, which is conveyed to a wastewater treatment plant; and centrifuged sludge. The remainder of the primary sludge stream is conveyed to a gravity separator, where the remainder of the primary sludge stream is separated into recovered oil and residual sludge. The residual oil is retrieved from the gravity separator.
An earth-boring tool system may include a drill string, and at least one or more sensors. The earth-boring tool system may receive data indicative of wear of at least part of a drilling tool, obtain labeled dull grading data for the drilling tool based on the received data, obtain a physics-based bit wear model based on one or more drilling parameters, generate one or more physics-based dull grading data labels based on the physics-based bit wear model, and train an artificial intelligence bit wear model based on the labeled dull grading data and the physics-based dull grading labels.
E21B 45/00 - Measuring the drilling time or rate of penetration
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
An annular seal system for sealing between a casing hanger and a wellhead housing, the system including an actuator ring having a rigid portion and a flexible portion, and a lockdown ring positioned adjacent the actuator ring. The annular seal system further includes a seal assembly capable of moving between a de-energized position and an energized position, wherein the seal assembly in the de-energized position has a defined a space between the seal assembly and the rigid portion of the actuator ring, wherein the seal assembly in the energized position has the space closed, wherein the rigid portion of the actuator ring is to contact a surface of the casing hanger, wherein the flexible portion of the actuator ring is to push the lockdown ring into engagement with the wellhead, and wherein the flexible portion of the actuator ring adapted is to axially compress to allow positional variation between the lockdown ring and the wellhead housing.
A wellbore system includes an upper head and a lower head coupled to the upper head by one or more fasteners. The wellbore system also includes a seal ring positioned within a seal pocket to engage the upper head to form a first seal interface between the upper head and the seal ring. The wellbore system includes a hanger arranged within a bore. The wellbore system includes a packoff positioned between the hanger and the lower head. The wellbore system includes one or more lock screws to apply a downward force to the packoff to establish a second seal interface between the packoff and the seal ring and a third seal interface between the packoff and the hanger.
A wellbore (10) characterized by: a borehole (12) traversing at least two zones; a string (16) disposed in the borehole (12) and traversing the at least two zones; a first valvular conduit (24) disposed in the string (16); a second valvular conduit (26) disposed in the string (16) to communicate with a different one of the at least two zones, the different one of the at least two zones being the other of the charge reservoir (18) and the target reservoir (20), the second valvular conduit (26) being configured to present a lower pressure drop for fluids flowing into the borehole (12) than out of the borehole (12).
A position sensor and a position sensor system, including a feeler, a force transfer element operably connected to the feeler, a force receiver operably connected to the force transfer element, and a force quantifier operably connected to the force receiver. A method for sensing position of a wet connector in a downhole environment, including running a position sensor on an upper wet connector to a target location, contacting a feeler block location on a lower wet connector, stroking the feeler, receiving a force at the force receiver, and communicating the received force to the force quantifier. A borehole system including a borehole in a subsurface formation, a position sensor disposed in the borehole.
A pressure sensor including a crystal housing, a transducer crystal disposed in the housing in vacuum conditions, a driver in contact with the crystal transducer, and a deflectable member in contact with the driver on one surface and exposed to ambient pressure on the opposite surface thereof. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a sensor connected to the string.
G01L 7/06 - Measuring the steady or quasi-steady pressure of a fluid or a fluent solid material by mechanical or fluid pressure-sensitive elements in the form of elastically-deformable gauges of the bellows type
A position sensor and a position sensor system, including a feeler, a force transfer element operably connected to the feeler, a force receiver operably connected to the force transfer element, and a force quantifier operably connected to the force receiver. A method for sensing position of a wet connector in a downhole environment, including running a position sensor on an upper wet connector to a target location, contacting a feeler block location on a lower wet connector, stroking the feeler, receiving a force at the force receiver, and communicating the received force to the force quantifier. A borehole system including a borehole in a subsurface formation, a position sensor disposed in the borehole.
A system (100; 600) and associated method (500; 550) for data handling in downhole operations uses a downhole tool to receive signals from a downhole environment and uses at least one processor that causes the system determine (554) encoded data for the signals, where the encoded data is based in part on coefficients associated with at least one predetermined fitting curve that is applied to data from different areas of the signals, and where the coefficients include (556) at least one difference between the data of the different areas of the signals and the at least one predetermined fitting curve. The system is further to transmit (508; 562) the encoded data (504; 558) from the downhole environment to a surface environment and also to determine (510; 566) at least one parameter or levels of an element in the downhole environment based in part on decoding (564) the encoded data.
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
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
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/18 - 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
G01V 3/30 - 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 electromagnetic waves
46.
REPRESENTATIVE PART, METHODS OF DESIGNING REPRESENTATIVE PARTS, METHODS OF FORMING AND TESTING REPRESENTATIVE PARTS, AND METHODS OF QUALIFYING ADDITIVE MANUFACTURING SYSTEMS
A method of forming a representative part correlating to an actual part. The method includes receiving an actual part design, analyzing the actual part design to identify one or more design elements, based on the one of more design elements; generating a representative part design incorporating the one or more design elements and having a differing overall shape comparative to the actual part design, and forming a representative part based on representative part design. A representative part correlating to an actual part includes one or more design elements of the actual part and a different overall shape relative to the actual part. A method of qualifying an additive manufacturing system or process for forming an actual part.
B29C 64/386 - Data acquisition or data processing for additive manufacturing
B33Y 50/02 - Data acquisition or data processing for additive manufacturing for controlling or regulating additive manufacturing processes
B29C 64/112 - Processes of additive manufacturing using only liquids or viscous materials, e.g. depositing a continuous bead of viscous material using individual droplets, e.g. from jetting heads
B29C 64/135 - Processes of additive manufacturing using only liquids or viscous materials, e.g. depositing a continuous bead of viscous material using layers of liquid which are selectively solidified characterised by the energy source therefor, e.g. by global irradiation combined with a mask the energy source being concentrated, e.g. scanning lasers or focused light sources
B29C 64/165 - Processes of additive manufacturing using a combination of solid and fluid materials, e.g. a powder selectively bound by a liquid binder, catalyst, inhibitor or energy absorber
B29C 64/393 - Data acquisition or data processing for additive manufacturing for controlling or regulating additive manufacturing processes
An additive manufacturing system may include an additive manufacturing device and a process map generation system. The process map generation system may generate an operational process map responsive to mathematical simulations of an additive manufacturing device, cause the additive manufacturing device to print a plurality of test structures responsive to the operational process map, detect one or more defects in each of the plurality of test structures, automatically update the operational process map responsive to the defects, and modify one or more operating parameters of the additive manufacturing device responsive to the updated operational process map.
B29C 64/386 - Data acquisition or data processing for additive manufacturing
B33Y 50/00 - Data acquisition or data processing for additive manufacturing
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
48.
SYSTEM AND METHOD FOR HANGER AND PACKOFF LOCK RING ACTUATION
A wellbore system includes a hanger lock energizing ring, a hanger lock ring, and a shoulder ring. The wellbore system further includes a seal energizing ring coupled to the shoulder ring. The wellbore system also includes a seal element being driven into an energized position by the seal energizing ring. The wellbore system further includes a seal lock energizing ring being driven to move via one or more extensions. The wellbore system includes a seal lock ring being supported, at least in part, by the seal energizing ring. Both the hanger lock ring and the seal lock ring are set, substantially simultaneously, responsive to movement of the one or more extensions.
E21B 33/04 - Casing heads; Suspending casings or tubings in well heads
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
Systems, methods, and a computer readable medium are provided for determining a minimum geometric dimension of an indication of an object being inspected using ultrasonic data. The system can include a computing device configured to receive ultrasonic data from an ultrasonic inspection device and to determine a contour of at least one indication of a defect. The computing device can apply a geometric template figure to the determined contour such that the geometric template figure is enclosed by the contour. At least one minimum geometric dimension of the indication can be determined based on determining a maximum dimension of the geometric template figure enclosed by the contour. The computing device can provide the at least one minimum geometric dimension of the indication.
A system (600) for determinations associated with pipe eccentricity in a downhole environment includes a downhole tool (116; 202; 620) having first transducers (210) to provide first shear horizontal waves to the downhole environment and second transducers (220) to provide first Lamb waves to the downhole environment, and includes memory (604A) storing instructions and a processor (604B) to execute the instructions from the memory to cause the system to receive, using the first transducers, second shear horizontal waves returned from the downhole environment and to receive, using the second transducers, second Lamb waves returned from the downhole environment, and further to determine shear horizontal third-interface echoes (TIEs) or Lamb TIEs from the second shear horizontal waves or the second Lamb waves and to determine the pipe eccentricity of the casing based in part on the one or more of the shear horizontal TIEs or the Lamb TIEs.
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
A system and associated method for data handling in downhole operations uses a downhole tool to receive signals from a downhole environment and uses at least one processor that causes the system determine encoded data for the signals, where the encoded data is based in part on coefficients associated with at least one predetermined fitting curve that is applied to data from different areas of the signals, and where the coefficients include at least one difference between the data of the different areas of the signals and the at least one predetermined fitting curve. The system is further to transmit the encoded data from the downhole environment to a surface environment and also to determine at least one parameter or levels of an element in the downhole environment based in part on decoding the encoded data.
E21B 47/13 - 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 by electromagnetic energy, e.g. of radio frequency range
A metal-to-metal seal for sealing an annular space between a well casing and a wellbore. The seal includes an inner portion and an outer portion, each portion including a central seal portion. The central seal portion has a concave shape in a de-energized state which curves towards the centerline of the seal and is capable of flexing radially outward towards surface of the annular space when energized. The central seal portion further includes at least one outer ridge extending outward away from the centerline of the seal and sealingly engages with the outer annular surface when energized.
An additive manufacturing system may include an additive manufacturing device and a process map generation system. The process map generation system may generate an operational process map responsive to mathematical simulations of an additive manufacturing device, cause the additive manufacturing device to print a plurality of test structures responsive to the operational process map, detect one or more defects in each of the plurality of test structures, automatically update the operational process map responsive to the defects, and modify one or more operating parameters of the additive manufacturing device responsive to the updated operational process map.
In at least one embodiment, a well inspection method and system enables transmission of an acoustic signal from a well inspection tool into a well structure and reception of return signals from the well structure at an array of receivers on the well inspection tool. The method and system enable performing of Short-Term Fourier Transform (STFT) on the return signals to generate spectrogram data that is used to determine short-term power spectra of the return signals. Time-dependent frequency response and location-dependent waveform propagation patterns are identified from the short-term power spectra. Cement bonding conditions is determined based on pattern matching using the time-dependent frequency response patterns and using the location-dependent waveform propagation patterns.
A wellhead annulus packoff and an associated method of energizing and de-energizing are disclosed. The wellhead annulus packoff includes at least one seal element, a hanger lockdown ring, a hanger lockdown energizing ring, a seal lockdown ring, a seal lockdown energizing ring, and one or more mechanical conditional operators, where the at least one seal element adapted to be energized with a first energizing force applied through a seal lockdown energizing ring and with the one or more mechanical conditional operators being engaged, where the seal lockdown ring is adapted to be energized with the first energizing force and with the one or more mechanical conditional operators being disengaged, and where the hanger lockdown ring is adapted to be energized with a second energizing force applied through a hanger lockdown energizing ring.
E21B 33/04 - Casing heads; Suspending casings or tubings in well heads
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
METHOD OF FORMING A SAND CONTROL DEVICE FROM A CURABLE INORGANIC MIXTURE INFUSED WITH DEGRADABLE MATERIAL AND METHOD OF PRODUCING FORMATION FLUIDS THROUGH A SAND CONTROL DEVICE FORMED FROM A CURABLE INORGANIC MIXTURE INFUSED WITH DEGRADABLE MATERIAL
A method of excluding particles entrained in formation fluids includes introducing a tubular into a wellbore, forming a sand control device formed from a curable inorganic cementitious mixture infused with an engineered degradable material about the tubular, introducing an external stimulus onto the sand control device causing the degradable material to dissolve, and flowing formation fluids through the sand control device into the tubular.
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
A line clamp configuration including a housing, a body attached to the housing, the body having a line contact surface, and a releaser disposed to separate the body from the housing. A control line clamp configuration including a downhole tool housing, an operable component of the downhole tool movable relative to the tool housing, a depending member on the operable component, a clamp body fastened to the housing by the depending member, a control line being releasable by removing the depending member from the clamp body. A control line clamp configuration including a split ring, a clamp body closing the split ring, and a switch to release the clamp body upon receipt of a signal. A borehole system including a borehole in a subsurface formation, a tool in the borehole, a clamp configuration operably connected to the tool.
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 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
58.
CONTROL LINE CLAMP CONFIGURATION, METHOD AND SYSTEM
A line clamp configuration including a housing, a body attached to the housing, the body having a line contact surface, and a releaser disposed to separate the body from the housing. A control line clamp configuration including a downhole tool housing, an operable component of the downhole tool movable relative to the tool housing, a depending member on the operable component, a clamp body fastened to the housing by the depending member, a control line being releasable by removing the depending member from the clamp body. A control line clamp configuration including a split ring, a clamp body closing the split ring, and a switch to release the clamp body upon receipt of a signal. A borehole system including a borehole in a subsurface formation, a tool in the borehole, a clamp configuration operably connected to the tool.
A system for determinations associated with pipe eccentricity in a downhole environment includes a downhole tool having first transducers to provide first shear horizontal waves to the downhole environment and second transducers to provide first Lamb waves to the downhole environment, and includes memory storing instructions and a processor to execute the instructions from the memory to cause the system to receive, using the first transducers, second shear horizontal waves returned from the downhole environment and to receive, using the second transducers, second Lamb waves returned from the downhole environment, and further to determine shear horizontal third-interface echoes (TIEs) or Lamb TIEs from the second shear horizontal waves or the second Lamb waves and to determine the pipe eccentricity of the casing based in part on the one or more of the shear horizontal TIEs or the Lamb TIEs.
Systems and methods for determining the orientation of the toolface of a rotating downhole tool using multiple sensors that measure different parameters related to the orientation of the toolface, where outputs of the different sensors are used by a Kalman filter which generates accurate predictions of the toolface orientation (state) at each of a series of time steps. The Kalman filter generates a state prediction based on a physical model and a previous state, and updates the prediction based on a received sensor output. Another sensor output is fed through a phase locked loop to generate a sine wave at the fundamental frequency of the sensor signal. The sine wave is used to synchronize another sensor signal that is provided to the Kalman filter for further adjustment of the state prediction.
A clamp for a line including a body, and a control line contact surface, the clamp being responsive to a selected input to facilitate displacement of the line. An expandable tool including a component having a first dimension prior to activation and a second dimension after activation, a control line disposed adjacent the component, and a clamp initially securing the control line, the clamp comprising at least one of 1) a fastener and 2) a body, at least a portion of either of which being responsive to a selected input to facilitate displacement of the control line. A method for deploying a tool with a control line including securing the control line to the tool, reacting the at least a portion of the clamp to the input, and displacing the control line. A borehole system including a borehole in a formation, and an expandable tool disposed in the borehole.
A fracture tool and a system includes a housing having a port, a sleeve disposed adjacent the housing and movable relative to the housing between a first position where the sleeve blocks the port and a second position where the sleeve unblocks the port, and a biaser operably connected between the housing and the sleeve. The biaser biases the sleeve to the first position. A method for fracturing a formation and producing a fluid includes opening a fracture sleeve, shifting a pressure-operated valve from an unarmed position to an armed position based upon the opening of the fracture sleeve. The method further includes applying fracture pressure to the formation, allowing the fracture sleeve to automatically close, actuating the valve with applied pressure, and flowing fluid through the valve. A borehole system including a borehole in a subsurface formation, and a fracture and production system disposed in the borehole.
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
63.
EARTH-BORING TOOL GEOMETRY AND CUTTER PLACEMENT AND ASSOCIATED APPARATUS AND METHODS
An earth-boring tool may include a tool body, at least one blade, and a rolling cutter pocket defined in the tool body adjacent the at least one blade. The earth-boring tool may further include a rolling cutter assembly disposed in the pocket. The rolling cutter assembly may include a plurality of cutting elements extending from a surface of the rolling cutter assembly. The earth-boring tool may also include at least one interface cutting element extending from a surface of the pocket.
Systems and methods for installing a coiled tubing pumping system in a well permit the use of a standard wellhead. A method for installing the coiled tubing pumping system includes the steps of connecting a continuous length of coiled tubing to the coiled tubing pumping sy stem, lowering the coiled tubing pumping system and coiled tubing into the production tubing, and temporarily supporting the weight of the coiled tubing pumping system with an installation kit. The method continues with the steps of cutting the continuous length of coiled tubing to form a coiled tubing segment attached to the coiled tubing pumping system, attaching a deployment assembly to an upper end of the coiled tubing segment connected to the coiled tubing pumping system, and lowering the deployment assembly, the coiled tubing segment and the coiled tubing pumping system into the well until the deployment assembly lands on the seating element.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
A clamp for a line including a body, and a control line contact surface, the clamp being responsive to a selected input to facilitate displacement of the line. An expandable tool including a component having a first dimension prior to activation and a second dimension after activation, a control line disposed adjacent the component, and a clamp initially securing the control line, the clamp comprising at least one of 1) a fastener and 2) a body, at least a portion of either of which being responsive to a selected input to facilitate displacement of the control line. A method for deploying a tool with a control line including securing the control line to the tool, reacting the at least a portion of the clamp to the input, and displacing the control line. A borehole system including a borehole in a formation, and an expandable tool disposed in the borehole.
An earth-boring tool includes at least one blade including at least one cutting element, at least one junk slot positioned adjacent the at least one blade, and a nozzle positioned in the at least one junk slot. The nozzle includes an outlet and an extension extending from a surface of the at least one junk slot to the outlet. The extension elevates the outlet to a position within a circumference of the at least one cutting element.
Systems and methods for determining the orientation of the toolface of a rotating downhole tool using multiple sensors that measure different parameters related to the orientation of the toolface, where outputs of the different sensors are used by a Kalman filter which generates accurate predictions of the toolface orientation (state) at each of a series of time steps. The Kalman filter generates a state prediction based on a physical model and a previous state, and updates the prediction based on a received sensor output. Another sensor output is fed through a phase locked loop to generate a sine wave at the fundamental frequency of the sensor signal. The sine wave is used to synchronize another sensor signal that is provided to the Kalman filter for further adjustment of the state prediction.
Systems and methods for installing a coiled tubing pumping system in a well permit the use of a standard wellhead. A method for installing the coiled tubing pumping system includes the steps of connecting a continuous length of coiled tubing to the coiled tubing pumping system, lowering the coiled tubing pumping system and coiled tubing into the production tubing, and temporarily supporting the weight of the coiled tubing pumping system with an installation kit. The method continues with the steps of cutting the continuous length of coiled tubing to form a coiled tubing segment attached to the coiled tubing pumping system, attaching a deployment assembly to an upper end of the coiled tubing segment connected to the coiled tubing pumping system, and lowering the deployment assembly, the coiled tubing segment and the coiled tubing pumping system into the well until the deployment assembly lands on the seating element.
A downhole valve system for use in a borehole is disclosed. The downhole valve system includes a first downhole component formed of a brittle material, a second downhole component, and a connection member. The connection member formed from a shape memory material and includes: an outer surface including an outer diameter; an inner surface including an inner diameter, one of the outer and inner diameter modifiable by applying a stimulus to the shape memory material; and a connection feature, complimentary of a connection feature of the second downhole component, formed on one of the outer surface and the inner surface. The connection member secured to the first downhole component at a corresponding surface of the one of the inner and outer diameter and to the second downhole component via the first connection feature and the second connection feature to connect the second downhole component to the first downhole component.
An isolation and filtration object including a volume of material having a first geometry wherein permeability is relatively lower, the geometry being that of a plug landable on a landing feature and a second geometry where permeability is relatively higher, the second geometry being larger than the first geometry and occupy a flow path in a borehole in which the plug is deployed. An isolation and filtration system including a housing, a plug seat in the housing, and an isolation and filtration object disposable on the plug seat. A borehole system including a borehole in a subsurface formation, a string in the borehole, and an isolation and filtration system connected to the string. A method for operating a borehole including migrating a plug to a seat in a housing, landing the plug in the seat, differentiating pressure across the plug, and transitioning the plug to the second geometry.
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
A multi position single direction sleeve valve includes a housing having a port therein, and a sleeve movable within the housing, the sleeve having a first portion including a radially extending opening therein and a second portion, the second portion being releasably attached to the first portion. A fracture system, including multi position single direction sleeve valve, and a bottom hole assembly having a profile engagable with the sleeve to shift a position of the sleeve relative to the housing, the bottom hole assembly having a debris barrier. A method including running the multi position single direction sleeve, including moving the sleeve from a closed position to an open position, and moving the sleeve from the 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 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
72.
ISOLATION AND FILTRATION OBJECT, SYSTEM, AND METHOD
An isolation and filtration object including a volume of material having a first geometry wherein permeability is relatively lower, the geometry being that of a plug landable on a landing feature and a second geometry where permeability is relatively higher, the second geometry being larger than the first geometry and occupy a flow path in a borehole in which the plug is deployed. An isolation and filtration system including a housing, a plug seat in the housing, and an isolation and filtration object disposable on the plug seat. A borehole system including a borehole in a subsurface formation, a string in the borehole, and an isolation and filtration system connected to the string. A method for operating a borehole including migrating a plug to a seat in a housing, landing the plug in the seat, differentiating pressure across the plug, and transitioning the plug to the second geometry.
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
73.
MULTI POSITION SINGLE DIRECTION SLEEVE, METHOD, AND SYSTEM
A multi position single direction sleeve valve includes a housing having a port therein, and a sleeve movable within the housing, the sleeve having a first portion including a radially extending opening therein and a second portion, the second portion being releasably attached to the first portion. A fracture system, including multi position single direction sleeve valve, and a bottom hole assembly having a profile engagable with the sleeve to shift a position of the sleeve relative to the housing, the bottom hole assembly having a debris barrier. A method including running the multi position single direction sleeve, including moving the sleeve from a closed position to an open position, and moving the sleeve from the 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 43/26 - Methods for stimulating production by forming crevices or fractures
A seal arrangement includes a body having a face seal, and a flexible arm extending from the body. The arm includes a contact seal. A flapper valve, includes a housing, a flapper and a flapper seat. The flapper seat includes a body having a face seal positioned to make sealing contact with the flapper in selected flapper positions A method for sealing a flapper valve includes closing a flapper toward a seat and making a seal, by deflecting a flexible arm of the flapper seat that supports a contact seal. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a seal arrangement disposed within or as a part of the string.
A seal section for use in a downhole submersible pumping system includes a lower chamber, an upper chamber and an intermediate guide section between the lower chamber and the upper chamber. The lower chamber includes a seal bag assembly that has a seal bag containing motor oil and an exterior space around the seal bag that contains high density oil that is denser than the motor oil. The upper chamber includes a volume of the high density oil at the bottom of the upper chamber and a gravity trap connected to the exterior space through an intermediate passage in the intermediate guide section. The gravity trap includes an opening submerged in the volume of high density oil in the upper chamber.
A downhole component includes a member formed from a first material. The member includes an end having a first plurality of external threads and a second end having a first plurality of internal threads. One of the first plurality of external threads and the second plurality of internal threads includes a first portion formed from the first material and a second portion formed from a second material that is distinct from the first material.
A treatment system including a settable and unsettable seal sub, an operation sub connected to the seal sub, the operation sub including a flow restrictor, and a selectively openable port biased to a closed position. A borehole system including a slickline, and a resettable seal connected to the slickline and runnable in the borehole on the slickline. A method for treating a formation adjacent a borehole including running the treatment system on a slickline to a target depth, flowing past the flow restrictor thereby causing the flow restrictor and a mandrel upon which the restrictor is mounted to move toward the seal sub, partially setting the seal sub and increasing pressure on the seal sub thereby fully setting the seal sub. A borehole system, including a borehole in a subsurface formation, a treatment system disposed within the borehole.
A permeable material including a plurality of hollow structures having a plurality openings therein allowing fluid transfer between an inside volume of the hollow structure and an environment outside of the hollow structure, and a bond between adjacent ones of the plurality of hollow structures. A downhole filtration tool including a mandrel, and the material disposed about the mandrel. An embodiment of a method for making a permeable material including aggregating a plurality of hollow structures into a mass, and bonding the structures together. An embodiment of a borehole system including a borehole in a subsurface formation, and the material, disposed in the borehole.
F03G 7/06 - Mechanical-power-producing mechanisms, not otherwise provided for or using energy sources not otherwise provided for using expansion or contraction of bodies due to heating, cooling, moistening, drying, or the like
79.
DOWNHOLE TOOL CONNECTION FORMED FROM MULTIPLE MATERIALS
A downhole component includes a member formed from a first material. The member includes an end having a first plurality of external threads and a second end having a first plurality of internal threads. One of the first plurality of external threads and the second plurality of internal threads includes a first portion formed from the first material and a second portion formed from a second material that is distinct from the first material.
E21B 17/042 - Couplings; Joints between rod and bit, or between rod and rod threaded
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
80.
SEAL CONFIGURATION FOR HIGH DENSITY LUBRICATION OILS
A seal section for use in a downhole submersible pumping system includes a lower chamber, an upper chamber and an intermediate guide section between the lower chamber and the upper chamber. The lower chamber includes a seal bag assembly that has a seal bag containing motor oil and an exterior space around the seal bag that contains high density oil that is denser than the motor oil. The upper chamber includes a volume of the high density oil at the bottom of the upper chamber and a gravity trap connected to the exterior space through an intermediate passage in the intermediate guide section. The gravity trap includes an opening submerged in the volume of high density oil in the upper chamber.
An apparatus for removing a casing from a borehole penetrating a formation in one run of the apparatus in the borehole includes: a carrier conveyed in the borehole; a non-incendiary hole former on the carrier to form a hole in the casing; a fluid discharge device on the carrier to discharge a fluid into the hole to wash an exterior portion of the casing; a casing puller on the carrier and having a casing grip to grip the casing to lift the casing or a portion of the casing out of the borehole; a mechanical cutter on the carrier to cut the casing; and a valve on the carrier to control fluid energy to least one of the non-incendiary hole former, the fluid discharge device, the casing puller, and the mechanical cutter.
E21B 31/16 - Grappling tools, e.g. tongs or grabs combined with cutting or destroying means
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 31/20 - Grappling tools, e.g. tongs or grabs gripping internally, e.g. fishing spears
82.
FLUORESCENCE SPECTROSCOPY FOR ESTIMATION OF FLUID CONTAMINATION
A method of analyzing a fluid includes acquiring a sample of the fluid extracted from a subterranean region proximate to a borehole, the borehole including an injected fluid, applying light having a first excitation wavelength to the fluid sample, and measuring a first fluorescence spectrum. The method also includes comparing the first fluorescence spectrum to a reference fluorescence spectrum corresponding to a fluid having injected fluid contamination and/or to a second fluorescence spectrum based on applying light having a second excitation wavelength to the fluid sample. The method further includes estimating a level of contamination of the fluid sample with the injected fluid based on the comparing.
A method of analyzing a fluid includes acquiring a sample of the fluid extracted from a subterranean region proximate to a borehole, the borehole including an injected fluid, applying light having a first excitation wavelength to the fluid sample, and measuring a first fluorescence spectrum. The method also includes comparing the first fluorescence spectrum to a reference fluorescence spectrum corresponding to a fluid having injected fluid contamination and/or to a second fluorescence spectrum based on applying light having a second excitation wavelength to the fluid sample. The method further includes estimating a level of contamination of the fluid sample with the injected fluid based on the comparing.
An apparatus for removing a casing from a borehole penetrating a formation in one run of the apparatus in the borehole includes: a carrier conveyed in the borehole; a nonincendiary hole former on the carrier to form a hole in the casing; a fluid discharge device on the carrier to discharge a fluid into the hole to wash an exterior portion of the casing; a casing puller on the carrier and having a casing grip to grip the casing to lift the casing or a portion of the casing out of the borehole; a mechanical cutter on the carrier to cut the casing; and a valve on the carrier to control fluid energy to least one of the non-incendiary hole former, the fluid discharge device, the casing puller, and the mechanical cutter.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 29/08 - Cutting or deforming pipes to control fluid flow
A permeable material including a plurality of hollow structures having a plurality openings therein allowing fluid transfer between an inside volume of the hollow structure and an environment outside of the hollow structure, and a bond between adjacent ones of the plurality of hollow structures. A downhole filtration tool including a mandrel, and the material disposed about the mandrel. An embodiment of a method for making a permeable material including aggregating a plurality of hollow structures into a mass, and bonding the structures together. An embodiment of a borehole system including a borehole in a subsurface formation, and the material, disposed in the borehole.
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
An asymmetric release configuration including a projection, a recess receptive to the projection the recess having a first shoulder that when brought into contact with the projection in a first direction loads the projection in a first way that results in a first release threshold, and a second shoulder that when brought into contact with the projection in a second direction loads the projection in a second way that results in a second release threshold, the second release threshold being different than the first release threshold. A method for operating a borehole including running a configuration into a borehole to a target depth, resisting a load on the configuration in a first direction to a first release threshold, and resisting a load in another direction to a second release threshold different than the first release threshold.
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
A method includes receiving data characterizing time-dependent lateral vibration of a shaft of a machine, the lateral vibration indicative of motion of at least a portion of the shaft perpendicular to a first direction. The lateral vibration is detected by a first sensor located at a first predetermined location on the shaft. The method further includes, receiving data characterizing time-dependent torsional vibration of the shaft, the torsional vibration indicative of rotation of the shaft around the first direction. The torsional vibration is detected by a second sensor located at a second predetermined location on the shaft. The method also includes calculating a coherence of the data characterizing time-dependent lateral vibration and the data characterizing time-dependent torsional vibration. The method further includes identifying, based on the coherence, a first frequency value in the frequency domain indicative of coupling between the time-dependent lateral vibration and the time-dependent torsional vibration.
Examples described herein provide for evaluating greenhouse gas emissions for a fluid for a hydrocarbon exploration and recovery operation. The method includes performing an emissions lifecycle analysis for the drilling and completion fluid. The method further includes determining a greenhouse gas emissions value for the drilling and completion fluid based at least in part on a result of the emissions lifecycle analysis. The method further includes modifying a portion of the hydrocarbon exploration and recovery operation based at least in part on the greenhouse gas emissions value.
Methods of forming a cutting element include sintering diamond particles at a temperature of at least about 1400° C. under a pressure of at least about 10 GPa in the absence of a metal solvent catalyst so as to form a polycrystalline diamond compact (PDC), providing a barrier material over at least a portion of the PDC, providing a carbide material and a metal binder comprising at least one transition metal element over the barrier material and the PDC, and performing a second sintering process comprising sintering the carbide material, the metal binder, the barrier material, and the PDC at a temperature of at least about 1400° C. under a pressure of at least about 5 GPa to form the cutting element. At least a portion of the PDC proximate an exposed exterior surface of the PDC may be at least substantially free of the metal binder.
C04B 35/528 - 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 obtained from carbonaceous particles with or without other non-organic components
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
A method for pulling casing includes disposing a casing modification and pulling tool having an element therein that includes a profile, causing the element to move radially outwardly into contact with a casing disposed radially outwardly of the tool, deforming the casing with the element, applying a load to the casing, and failing the casing at the deformation. A system for pulling casing includes a casing modification tool having an element radially displaceable into a casing disposed radially outwardly thereof, the element configured to deform the casing, a casing spear operably connected to the casing modification tool, the spear configured to apply a load to the casing to fail the casing at the deformation. A borehole system includes a borehole in a subsurface formation, a casing disposed in the borehole, and a casing modification and pulling tool disposed in the casing.
In gas hydrate inhibitor formulations used to prevent or inhibit the formation of gas hydrates in multi-phase fluids, such as hydrocarbon production fluids, conventional solvents can be largely replaced by at least one organic carbonate solvent, such as ethylene carbonate, propylene carbonate, and/or glycerol carbonate. The gas hydrate inhibitors in these formulations may be, but are not necessarily limited to, polyesteramides, polyvinylpyrrolidones, and the like. The use of an organic carbonate in the gas hydrate inhibitor formulation can improve the capability of the formulation for inhibiting or preventing gas hydrate formation in a multi-phase fluid.
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C10L 3/10 - Working-up natural gas or synthetic natural gas
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
A method for pulling casing includes disposing a casing modification and pulling tool having an element therein that includes a profile, causing the element to move radially outwardly into contact with a casing disposed radially outwardly of the tool, deforming the casing with the element, applying a load to the casing, and failing the casing at the deformation. A system for pulling casing includes a casing modification tool having an element radially displaceable into a casing disposed radially outwardly thereof, the element configured to deform the casing, a casing spear operably connected to the casing modification tool, the spear configured to apply a load to the casing to fail the casing at the deformation. A borehole system includes a borehole in a subsurface formation, a casing disposed in the borehole, and a casing modification and pulling tool disposed in the casing.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 31/16 - Grappling tools, e.g. tongs or grabs combined with cutting or destroying means
E21B 31/20 - Grappling tools, e.g. tongs or grabs gripping internally, e.g. fishing spears
A method of defining a BHA design includes performing a numerical optimization process, which includes applying a bottom hole assembly (BHA) design criterion using a numerical optimization algorithm to identify a set of BHA designs selected from a plurality of possible BHA designs, evaluating multiple objective functions for each BHA design of the set of BHA designs based at least in part on a modeling constraint, and identifying a pareto-front of a solution space of the multiple objective functions using the numerical optimization algorithm. The method also includes selecting a data point from the pareto-front using a cost function, selecting a BHA design from the set of BHA designs using the selected data point, and building a BHA using the selected BHA design to be deployed downhole in a wellbore.
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 41/00 - Equipment or details not covered by groups
A cutting element assembly includes a cutting element and a sleeve having a cutter-receiving aperture configured to receive at least a portion of the cutting element within the cutter-receiving aperture. The cutting element assembly may also include a retention element rotatably coupling the cutting element to the sleeve and a biasing member disposed between the cutting element and the sleeve. The biasing member may be configured to bias the cutting element relative to the sleeve. A method of forming a downhole tool includes forming a bit body including at least one blade, securing at least one sleeve to the blade, disposing at least one biasing member within the cutter-receiving aperture, and inserting a cutting element into the cutter‑receiving aperture of the at least one sleeve, such that the at least one biasing member is disposed between the at least one sleeve and the cutting element.
Examples described herein provide for evaluating greenhouse gas emissions for a fluid for a hydrocarbon exploration and recovery operation. The method includes performing an emissions lifecycle analysis for the drilling and completion fluid. The method further includes determining a greenhouse gas emissions value for the drilling and completion fluid based at least in part on a result of the emissions lifecycle analysis. The method further includes modifying a portion of the hydrocarbon exploration and recovery operation based at least in part on the greenhouse gas emissions value.
A method of defining a BHA design includes performing a numerical optimization process, which includes applying a bottom hole assembly (BHA) design criterion using a numerical optimization algorithm to identify a set of BHA designs selected from a plurality of possible BHA designs, evaluating multiple objective functions for each BHA design of the set of BHA designs based at least in part on a modeling constraint, and identifying a pareto-front of a solution space of the multiple objective functions using the numerical optimization algorithm. The method also includes selecting a data point from the pareto-front using a cost function, selecting a BHA design from the set of BHA designs using the selected data point, and building a BHA using the selected BHA design to be deployed downhole in a wellbore.
A cutting element assembly includes a cutting element and a sleeve having a cutter-receiving aperture configured to receive at least a portion of the cutting element within the cutter-receiving aperture. The cutting element assembly may also include a retention element rotatably coupling the cutting element to the sleeve and a biasing member disposed between the cutting element and the sleeve. The biasing member may be configured to bias the cutting element relative to the sleeve. A method of forming a downhole tool includes forming a bit body including at least one blade, securing at least one sleeve to the blade, disposing at least one biasing member within the cutter-receiving aperture, and inserting a cutting element into the cutter-receiving aperture of the at least one sleeve, such that the at least one biasing member is disposed between the at least one sleeve and the cutting element.
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 10/43 - 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
98.
POLYCRYSTALLINE DIAMOND COMPACT CUTTING ELEMENTS, EARTH-BORING TOOLS INCLUDING SUCH CUTTING ELEMENTS, AND RELATED METHODS OF MAKING AND USING SAME
Methods of forming a cutting element include sintering diamond particles at a temperature of at least about 1400ºC under a pressure of at least about 10 GPa in the absence of a metal solvent catalyst so as to form a polycrystalline diamond compact (PDC), providing a barrier material over at least a portion of the PDC, providing a carbide material and a metal binder comprising at least one transition metal element over the barrier material and the PDC, and performing a second sintering process comprising sintering the carbide material, the metal binder, the barrier material, and the PDC at a temperature of at least about 1400ºC under a pressure of at least about 5 GPa to form the cutting element. At least a portion of the PDC proximate an exposed exterior surface of the PDC may be at least substantially free of the metal binder.
A hanger running tool includes a mandrel. The hanger running tool also includes a mandrel protrusion, the mandrel protrusion extending radially outward from the mandrel. The hanger running tool includes a hold down nut coupled to the mandrel and arranged axially uphole of the mandrel protrusion. The hanger running tool includes a thrust collar coupled to the mandrel and arranged axially downhole of the mandrel protrusion. The hanger running tool includes a void cavity defined, at least in part, by the hold down nut, the thrust collar, and the mandrel, wherein the mandrel protrusion is positioned within the void cavity. The hanger running tool also includes a bearing system positioned within the void cavity.
Methods and systems for predicting downhole measurement data at the earth surface include predicting a first estimate value of a property of interest using a first processor in a downhole tool using a first predictor and predicting a second estimate value of the property of interest using a second processor of a surface unit and using a second predictor, the second predictor including identical data processing as the first predictor. A measurement value of the property of interest is obtained using a sensor arranged in the downhole tool. The first processor compares the measurement value with the first estimate value and determines if the measurement value is within a predetermined threshold relative to the first estimate value. In response to the measurement value being within the predetermined threshold of the first estimate value, a wellbore operation based on the second estimate value is performed using the second processor.
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 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
E21B 47/13 - 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 by electromagnetic energy, e.g. of radio frequency range
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
