A method for determining a health indicator parameter of a fluid are described. The method can include contacting at least one first functionalized electrode included in a plurality of functionalized electrodes of a sensing unit with a fluid. The method can also include generating a first electrical signal within the fluid by the at least one first functionalized electrode. The method can further include receiving, by at least one second functionalized electrode included in the plurality of functionalized electrodes of the sensing unit, a second electrical signal in response to the first electrical signal. The sensing unit can determine a health indicator parameter of the fluid based on the second electrical signal. The health indicator parameter can be associated with an electrochemical response signal included in the second electrical signal. The sensing unit can provide the health indicator parameter to a computing device communicably coupled to the sensing unit.
2.
BORON TRIFLUORIDE AS A QUENCH GAS FOR NEUTRON PROPORTIONAL COUNTERS
A neutron proportional counter is provided. The proportional counter can include a chamber and a gas mixture. The chamber includes an anode and a cathode. The gas mixture is contained within the chamber and includes at least one neutron sensitive fill gas and a quench gas including BF3. In certain embodiments, the neutron sensitive fill gas can be configured for detection of thermal neutrons (e.g., He-3), fast neutrons (e.g., He-4, H2), or both (e.g., UF6).
A method of assembling a borehole screen assembly includes placing a screen around a base pipe followed by an end ring having a skive cut to allow fitment with the screen by sliding along the skive cut. The assembly can be completed with welds.
A method of ultrasonic inspection includes generating, by a phased array ultrasonic probe, a first ultrasonic beam propagating in a fluid and incident at a first angle to a target surface in response to receipt of first instructions. Ultrasonic echoes from first beam reflection by the target are measured and corresponding ultrasonic measurement signals are output. At least one environmental sensor measures at least one fluid property and outputs corresponding environmental signals. One or more processors determine a current speed of sound within the fluid from the ultrasonic measurement signals and environmental signals. Second instructions including a second angle are generated by the processors, based on the current speed of sound, when the current speed of sound differs from a predetermined speed of sound by more than a speed threshold. The ultrasonic probe generates a second ultrasonic beam at the second angle in response to receipt of the second instructions.
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
A pressure calibration system includes a manual pump and pressure adjustment subsystem. The pump outputs pressurized fluid to the adjustment subsystem in response to manual actuation. The adjustment subsystem is configured to automatically adjust the pressure in fine increments after the manual pump pressurizes the fluid within a tolerance range of a pressure set point. A user interface is further configured generate annunciations regarding the fluid pressure.
A method for is provided. The method can include receiving data characterizing a first measurement image having a first state and a first set of three-dimensional coordinate data corresponding to the first measurement image. The first measurement image can include two-dimensional image data. The method can also include receiving data characterizing at least one geometric dimension determined for the first measurement image. The method can further include receiving data characterizing a second measurement image having a second state and a second set of three-dimensional coordinate data corresponding to the second measurement image. The method can also include applying the first state of the first measurement image to the second measurement image. The method can further include displaying at least one second geometric dimension determined using the second set of three-dimensional coordinate data.. Related systems performing the method are also provided.
F01D 21/00 - Shutting-down of machines or engines, e.g. in emergency; Regulating, controlling, or safety means not otherwise provided for
G06T 7/70 - Determining position or orientation of objects or cameras
G01B 11/03 - Measuring arrangements characterised by the use of optical techniques for measuring length, width, or thickness by measuring coordinates of points
G01B 11/14 - Measuring arrangements characterised by the use of optical techniques for measuring distance or clearance between spaced objects or spaced apertures
A demulsifying additive cornprising a branched aliphatic compound may be introduced to a stream containing mixtures of or emulsions of oil and water in an effective amount to separate water from the oil in the strearn, such as separating oil from emulsified oil-in-water and/or separating water from emulsified water-in-oil in a production fluid. The branched aliphatic compound may be grafted with a polyether via a crosslinking reaction. Alternatively, branched aliphatic compounds may be crosslinked together.
This disclosure is directed to the use of a portable Surface Enhance Raman Spectroscopy method to detect, quantify, and/or monitor corrosion inhibitors that are present in fluids in a wide range of concentrations in order to manage corrosion treatment in oil and gas production and refining systems or other industrial systems and to reduce the amount of time spent in obtaining data that is reliable and useful for corrosion control.
C07C 321/04 - Thiols having mercapto groups bound to acyclic carbon atoms of an acyclic saturated carbon skeleton
C07C 323/12 - Thiols, sulfides, hydropolysulfides or polysulfides substituted by halogen, oxygen or nitrogen atoms, or by sulfur atoms not being part of thio groups containing thio groups and singly-bound oxygen atoms bound to the same carbon skeleton having the sulfur atoms of the thio groups bound to acyclic carbon atoms of the carbon skeleton the carbon skeleton being acyclic and saturated
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
A backup ring assembly has a plurality of radially offset ring members including an outermost ring member formed from plurality of axially extending segments. Each of the plurality of axially extending segments includes an outer surface. A first interlock member support is coupled to the outer surface of one of the plurality of axially extending segments of the outer most ring member. A second interlock member support is coupled to the outer surface of an another one of the plurality of axially extending segments of the outermost ring member. An interlock member includes a first end supported at the first interlock member support and a second end supported at the second interlock member support. The interlock member restrains radially outward expansion of the ring and circumferential expansion of a gap extending between the one of the axially extending segments and the another one of the axially extending segments.
Systems, methods, and a computer readable medium are provided for automatically controlling a pump in an oil production environment. Sensor data can be collected from pump machinery and can be used to generate an advisory statement identifying a change in pump operation in regard to one or more operating conditions. The advisory plan can be used to determine an optimization action plan to maintain the operation of the pump machinery with respect to the operating conditions. The optimization action plan can include an action, a parameter, and a parameter variable and can be transmitted to a computing device configured within a supervisory control and data acquisition system and coupled to the pump machinery. The computing device can execute the optimization action plan to control the pump machinery with respect to the operating conditions.
A method for generating a well completion plan includes: evaluating a plurality of different well completion plans using a reservoir simulator to calculate dynamic flows of fluid through a subsurface formation, each well completion plan having a flow control device with location and associated flow setting or rating, and optionally a packer and location to provide output data for each well completion plan evaluation; developing a surrogate reservoir model using the output data and input data for each well completion plan evaluation; using intelligent sequential sampling of the output and input data for each well completion plan evaluation to provide intelligent sequential sampling data in response to the surrogate reservoir model not meeting a validation criterion; updating the surrogate reservoir model using the intelligent sequential sampling data; and iterating the using and the updating using a latest surrogate reservoir model until the latest surrogate reservoir model meets the validation criterion.
G06Q 10/0637 - Strategic management or analysis, e.g. setting a goal or target of an organisation; Planning actions based on goals; Analysis or evaluation of effectiveness of goals
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A method and apparatus for determining a pressure in an annulus between an inner casing and an outer casing. An acoustic transducer is disposed within the casing at a selected depth within the inner casing and is configured to generate an acoustic pulse and receive a reflection of the acoustic pulse from the inner casing. A time of flight is measured of the acoustic pulse to the inner surface of the inner casing. An inner diameter of the inner casing is determined from the time of flight. The pressure in the annulus is determined from the inner diameter. A processor can be used to measure time and determine inner diameter and annulus pressure.
E21B 47/08 - Measuring diameters or related dimensions at the borehole
G01L 9/00 - Measuring steady or quasi-steady pressure of a fluid or a fluent solid material by electric or magnetic pressure-sensitive elements; Transmitting or indicating the displacement of mechanical pressure-sensitive elements, used to measure the steady or quasi-steady pressure of a fluid or fluent solid material, by electric or magnetic means
13.
METHODS AND COMPOUNDS FOR REMOVING NON-ACIDIC CONTAMINANTS FROM HYDROCARBON STREAMS
An extraction solvent comprised of one or more ethyleneamines having structure (I), (II), or (III): R1R2N(R3NR4)NR5R6 where R1-R6 can independently be H, C1-C4 linear or branched alkyl, amido (RRNC=0), or hydroxyalkyl, where each R in the amido group independently H or C1 alkyl, and where x ranges from 1 to 6, may be contacted with a hydrocarbon stream to remove or extract non-acidic contaminants, such as thiophenes, benzothiophenes, alkyl sulfides, alkyl disulfides, mercaptans, aromatics, oxygenates, metals, olefins, and combinations thereof, from the hydrocarbon stream. The extraction solvent may include co-solvents and the hydrocarbon stream may be in gas and/or liquid form.
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
A tool for use in a wellbore includes a first tubular having an outer surface and an inner surface defining a first conduit. The inner surface includes a dog engagement zone. A second tubular includes an outer surface portion and an inner surface portion defining a second conduit. The second tubular extends into the first conduit and including a dog opening having a dog support. A dog is arranged in the dog opening. The dog includes an outer surface contour that engages with the dog engagement zone and an inner surface including a recess that engages with the one or more dog supports. The dog is moveably retained between the first tubular and the second tubular.
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 gas-lift well including a casing extending down a wellbore, production tubing extending within the casing, a gas system for inserting compressed gas into an annular space between the casing and the production tubing, at least one gas-lift input extending from the annular space, through the production tubing, and to an interior of the production tubing, and at least one fluid flow regime modifier within the production tubing and at least partially within a fluid column of the production tubing, the at least one fluid flow regime modifier configured to reduce fluid fallback and impart a turbulent flow regime to at least a portion of the fluid column.
A guiding sleeve for aligning downhole tubulars includes a body having a first end portion, a second end portion and an intermediate portion extending therebetween. The first end portion is receptive of a terminal end of a first tubular and the second end portion includes a guiding feature that promotes axial alignment of the first tubular with a second tubular.
A pump that is configured to lift fluids through a tubing string includes a gas mitigation system and a screen flush module. The gas mitigation system has a canister with an interior and an intake screen. The gas mitigation system further includes an intake tube that extends into the canister. The screen flush module is configured to flush solids particles trapped in the intake screen.
A well fluid centrifugal pump (19) has a shaft passage (59) in the shaft (37). The shaft passage has an open upper end above the impellers (45) and a closed lower end below the impellers. An outlet port (61) extends laterally from the shaft passage. A gas-lock re-priming device (63) in the shaft passage diverts a portion of well fluid in the discharge adapter bore (41) through the shaft passage and out the outlet port. The re-priming device may be a pressure actuated valve (63) that is biased to a closed position and opens when the pressure in the discharge adapter bore drops below a minimum. Alternately, the re-priming device may be an orifice member (123) with an orifice passage (125) that continuously diverts a portion of the well fluid in the discharge adapter bore (119) out the outlet port.
An apparatus for monitoring deployment of filtration media at least partially surrounding a tubular disposed in a borehole penetrating the earth includes a carrier configured to be conveyed through the tubular, a low-frequency acoustic wave source disposed on the carrier and configured to transmit acoustic waves in a frequency that is less than 3000 Hz into the tubular, and an acoustic wave receiver disposed on the carrier a distance from the low-frequency acoustic wave source and configured to receive acoustic waves transmitted by the low-frequency acoustic wave source. The apparatus also includes a controller configured to compare data characterizing the received acoustic waves to reference data characterizing acoustic waves with the filtration media not deployed.
G01S 3/80 - Direction-finders for determining the direction from which infrasonic, sonic, ultrasonic, or electromagnetic waves, or particle emission, not having a directional significance, are being received using ultrasonic, sonic, or infrasonic waves
Systems, methods, and computer-readable medium for generating a three- dimensional fracture network model are provided. The method can include receiving reflected acoustic signal measurements acquired in response to emission of acoustic waves by one or more sensors disposed in a wellbore formed within a target region. Each reflected acoustic signal measurement represents a strength of a reflected acoustic wave as a function of time measured in at least one predetermined direction oriented with respect to an axis of the wellbore. A fracture extension estimate is generated for each of the reflected acoustic signal measurements. A three-dimensional fracture network model is generated corresponding to the fracture extension estimates generated for each of the plurality of reflected acoustic measurements. The generated fracture network model is output for display or use in modeling environments.
A submersible well pump (13) has diffusers (49) fixed within the housing (25) and an impeller (63) mounted between each of the diffusers. Spacer sleeves (71) located between and in abutment with hubs (65) of adjacent ones of the impellers define a stack (73) wherein the impellers rotate in unison with the shaft (29) and are axially movable in unison with each other relative to the shaft. A stop shoulder (75) on the shaft abuts the lower end of the stack. A spring (77) mounted in compression around the shaft in abutment with the upper end of the stack urges the lower end of the stack against the stop shoulder. Upward movement of the stack requires further compression of the spring. Up thrust and down thrust gaps (81, 87) between each impeller and adjacent diffusers prevent up thrust and down thrust from being transferred to any of the diffusers.
A pumping system has a motor, a shaft assembly connected to the motor, a production pump connected to the shaft assembly and driven by the motor, an electrical generator connected to the shaft assembly and driven by the motor, an oil circulation pump connected to shaft assembly and driven by the motor, and a heat exchanger. The heat exchanger includes an outer housing, a heat exchange core inside the outer housing, a plurality of heat exchange fluid passages extending through the heat exchange core, and one or more thermoelectric cooling modules in contact with the outer housing and the heat exchange core. The one or more thermoelectric cooling modules are powered by the output from the electrical generator. The oil circulation pump circulates motor lubricant oil between the motor and the heat exchanger.
A pumping system has a motor, a shaft assembly connected to the motor, a production pump connected to the shaft assembly and driven by the motor, an electrical generator connected to the shaft assembly and driven by the motor, an oil circulation pump connected to shaft assembly and driven by the motor, and a heat exchanger. The heat exchanger includes an outer housing, a heat exchange core inside the outer housing, a plurality of heat exchange fluid passages extending through the heat exchange core, and one or more thermoelectric cooling modules in contact with the outer housing and the heat exchange core. The one or more thermoelectric cooling modules are powered by the output from the electrical generator. The oil circulation pump circulates motor lubricant oil between the motor and the heat exchanger.
A cleaning agent comprising a polyacrylate terpolymer and a maleic olefin compound may be added to an aqueous system having a metal surface, such as a metal surface of a heat exchanger, in a concentration sufficient to remove fouling deposits from the metal surface in neutral or alkaline conditions. The removal of fouling deposits with the application of the cleaning agent may occur while the system is shut down or in service.
A test skid for a pumping system is configured to evaluate the performance of a pump. The test skid includes a motor and a torque-thrust chamber connected between the motor and the pump. The torque-thrust chamber has a torque meter and a thrust bearing. The thrust bearing is positioned between the torque meter and the motor such that the torque meter is connected directly to the pump through a pump input shaft. In this configuration, the torque meter measures the torque applied directly to the pump without the need to account for losses through an intermediate thrust bearing.
Systems and methods for sealing a pothead connection to prevent external fluids from leaking into an ESP motor. In one embodiment, a pothead housing has a set of sealing assemblies, where each of the sealing assemblies has a sealing body that is positioned in a port of the motor's housing to form a direct seal against both a corresponding motor lead extension cable and the motor housing. The sealing assembly has a pothead terminal that is electrically connected to the conductor of the corresponding cable. When the pothead is secured to the motor housing, the pothead terminal engages a corresponding motor housing terminal positioned in the port. The motor housing terminal is connected to the motor windings, so this electrically connects the motor lead to the windings. An insulator is positioned to electrically isolate the motor housing terminal from the housing itself.
A multistage centrifugal pump has a rotatable shaft, a plurality of pump stages and a thrust module. Each of the plurality of pump stages has an impeller connected to the rotatable shaft and a stationary diffuser. The thrust module has a thrust runner and a unitary thrust pad. The unitary thrust pad has an axial wear face adjacent the thrust runner and a radial wear surface adjacent the rotatable shaft. The axial wear face and radial wear surface are integrated as a unitary component. The unitary thrust pad is secured to a thrust pad support with threaded fasteners that are torqued to a predetermined extent.
A shaft coupling for connecting an upper shaft with a lower shaft within a pumping system is designed to handle a large tensile load between the upper and lower shafts. In some embodiments, the upper shaft includes a shaft ring groove and the coupling has a body and a first receiving chamber within the body that receives an end of the upper shaft. The coupling also includes an upper internal groove extending into the body from the first receiving chamber and an upper split ring that is configured to be compressed into a position occupying both the upper internal groove and the shaft ring groove of the upper shaft. Set screws compress the upper split ring into the shaft ring groove of the upper shaft. In another embodiment, the coupling includes a plurality of locking screws that extend through the body into corresponding lock screw grooves in the upper and lower shafts.
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04D 29/044 - Arrangements for joining or assembling shafts
F04D 29/054 - Arrangements for joining or assembling shafts
29.
TIME DIVISION MULTIPLEXING OF DISTRIBUTED DOWNHOLE SENSING SYSTEMS
Downhole fiber optic interrogation systems are described. The systems include a fiber optic control system, a first sensing system, a second sensing system, an optical fiber disposed within a well, and an optical switch arranged between the optical fiber and the first and second sensing systems, wherein the fiber optic control system performs time division multiplex control of the optical switch wherein the first sensing system is operably connected to the optical fiber and the second sensing system is not connected to the optical fiber, and further controls the optical switch such that the second sensing system is operably connected to the optical fiber and the first sensing system is not connected to the optical fiber.
G01V 8/24 - Detecting, e.g. by using light barriers using multiple transmitters or receivers using optical fibres
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
G02B 6/04 - Light guides; Structural details of arrangements comprising light guides and other optical elements, e.g. couplings formed by bundles of fibres
Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat wastewater and/or to inhibit and/or prevent fouling of contaminants onto surfaces.
An inflow promotion arrangement including a housing; and a promotion configuration within the housing, the promotion configuration actuatable by fluid from a relatively higher productivity index zone of a wellbore.
A seal system for downhole use in a surrounding tubular includes a seal support including a frusto-conical surface, and a seal member positioned about the seal support. The seal member includes a seal support member including first side having a recess, a second, opposing side, and a seal element coupled to the second, opposing side. The seal element is engageable with the surrounding tubular. An expansion limiter is arranged between the seal support and the seal member. The expansion limiter is positioned in the recess of the seal support member to limit axial movement of the seal member relative to the frusto-conical surface.
A method for deploying a sand screen in a borehole penetrating the earth includes: disposing the sand screen in an unexpanded form in the borehole, the sand screen at least partially surrounding a base-pipe; and activating the sand screen in the unexpanded form by applying at least one of an activation fluid and heat to the sand screen causing the sand screen to expand into an expanded form. The method further includes: conveying a downhole tool through the base-pipe, the downhole tool being configured to sense a property derived from at least one of expansion and non-expansion of the sand screen as a function of distance into the borehole to provide sensed data as a function of distance into the borehole; and identifying one of an expanded state and an unexpanded state of the sand screen using the sensed data as a function of distance into the borehole.
An object seat including a seat host having a seal bore therein, a seat body dimensioned to be receivable in the seal bore, the seat body having an object receptor. A method for carrying out a pressure operation in a borehole including seating an object on an object receptor of a seat body, the seat body disposed in a seat host, the seat host disposed in the borehole, pressuring against the object, and moving the seat body along an interface between the seat body and the seat host to create a fluid flow pathway through the seat body and seat host interface. A borehole system including a borehole in a formation, an object seat as in any prior embodiment disposed in the borehole.
E21B 34/06 - Valve arrangements for boreholes or wells 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
An object removal enhancement arrangement including a second object comprising a material configured to enhance degradation of a first object. A resource recovery system including a tubular string disposed in a formation, a first seat disposed in the tubular string, a second seat disposed in the tubular string, an object receivable in the second seat upstream of the first seat, the object comprising a material to enhance degradation of an object receivable in the first seat. A method for enhancing response time for degrading degradable objects in a system including landing a first object on a first seat, pressuring against the first object, landing a second object on a second seat uphole of the first object, releasing a material of the second object to an environment between the first seat and the second seat.
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
The present disclosure is directed to additives comprising modified cationic starches that may be applied to a production fluid at high temperatures, such as temperatures ranging from about 80 °C to about 300 °C, for separating water from an emulsion in the production fluid.
The disclosure relates to the use of ionic liquids as paraffin inhibitors, pour point depressant or cold flow improvers in the production, treatment and refining of hydrocarbon fluids.
A method of inhibiting corrosion of a metallic surface in contact with an acidic or aqueous fluid comprises contacting the fluid with a corrosive inhibiting effective amount of an ionic liquid of the formula; R1R2R3R4A+X (II) ; or R1R2R3A+R8A+R5R8R7 X- (111) where X in formula (111) is an anion selected from sulfur containing anions, hydroxycarboxylates and mixtures thereof; and X in formula (11) is a hydroxycarboxylate or a sulfur containing anion selected from bisulfates, thiocyanates, thiocarbonates, dithiocarbamates of the formula wherein Ri and R2 are selected from C1-20 alkyl groups, xanthates of formula wherein R is a C-I-20 alkyl, sulfides of the formula RS- wherein R is a C1-20 alkyl, anionic polysulfides of the formula RS(S)xS wherein R is a C1-2r3 alkyl and x is 1 to 5, and anionic thiols RSH where R is ¨(CH)x)H and x is from 1 to 4, alkylated thiols; anionic sulfonyl alcohols,
A downhole tool includes a tool member having a radially outer surface and a radially inner surface. The radially inner surface includes an angled section. A drive member is axially spaced from the tool member. The drive member includes a radially outer surface portion and a radially inner surface portion. The radially outer surface portion includes an angled portion. A seal element is provided on the drive member. The seal element includes a first portion coupled to the radially outer surface portion and a second portion that is radially outwardly disengagable from the radially outer surface portion in response to one of fluid pressure and fluid flow.
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 33/126 - Packers; Plugs with fluid-pressure-operated elastic cup or skirt
E21B 33/128 - Packers; Plugs with a member expanded radially by axial pressure
41.
METHODS OF MANUFACTURING POLYOLEFIN DRAG REDUCING AGENTS
A process of manufacturing a polyolefin drag reducing agent comprises: injecting a catalyst and a drag reducing agent forming component comprising (i) at least one olefin monomer, or (ii) at least one olefin oligomer, or a combination of (i) and (ii) into a temporary container comprising a container material, sealing the temporary container; allowing the drag reducing agent forming component to polymerize in the sealed temporary container to form the polyolefin drag reducing agent; and at least partially dissolving the container material. The container material includes an ethylene vinyl acetate copolymer, an ethylene vinyl alcohol copolymer, a polyvinylpyrrolidone, an ethylene vinylpyrrolidone copolymer, a vinylpyrrolidone vinyl acetate copolymer, a polyvinyl acetate, a polyvinyl alcohol, a polyethylene glycol, a polysaccharide or its derivative, or a combination comprising at least one of the foregoing, provided that when the container material comprises polyvinyl acetate or polyvinyl alcohol, the temporary container is coated or has two or more layers.
C08F 220/00 - Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and only one being terminated by only one carboxyl radical or a salt, anhydride, ester, amide, imide, or nitrile thereof
42.
EXTRACTING HYDROCARBONS FROM A SUBTERRANEAN HYDROCARBON RESERVOIR BASED ON AN ARTIFICIAL LIFT PLAN
Examples of techniques for extracting hydrocarbons from a subterranean hydrocarbon reservoir based on an artificial lift plan are disclosed. In one example implementation according to aspects of the present disclosure, a method includes performing, by a processing device, an evaluation of an artificial lift approach that can be operated at a well having a subterranean hydrocarbon reservoir, the evaluation being based at least in part on a static factor associated with operating the artifical lift approach in the well and a dynamic factor associated with operating the artifical lift approach at a operating condition. The method further includes generating, by the processing device, an artificial lift plan based at least in part on the evaluation. The method further includes extracting the hydrocarbons from the subterranean hydrocarbon reservoir based on the artificial lift plan by operating, at the well, the artifical lift approach.
An element backup including a first ring defining an axis; a first parting line through the first ring, the first parting line having a first plurality of generally axially extending segments and a first generally non-axially extending segment extending between the first plurality of axially extending segments; a second ring defining an axis; a second parting line through the second ring, the second parting line having a second plurality of generally axially extending segments and a second generally non-axially extending segment extending between the second plurality of axially extending segments; and an interconnection releasably securing the first and second rings to one another.
A cutter element for an earth-boring tool, comprising a polycrystalline diamond (PCD) volume joined at an interface boundary to a cemented carbide substrate. The PCD volume includes a rake face opposite the interface boundary, an edge of the rake face being suitable as a cutting edge of the cutter element. The PCD volume comprises a plurality of strata directly joined to each other at inter-strata boundaries, in which each of a first plurality of the strata comprises PCD material having a first diamond content; each of a second plurality of the strata comprises PCD material having a second diamond content; the second diamond content being greater than the first diamond content; and the strata of the first and second pluralities disposed in an alternating arrangement with respect to each other. The strata are configured and arranged such that a radial line through the edge and a centroid of the interface boundary intersects, within 1,000 microns from the edge, each of the inter-strata boundaries, and the respective tangent plane to each inter-strata boundary at the respective intersection is disposed relative to the radial line at no less than a minimum angle of 30°.
A fracturing system including a fracturing sleeve having an opening sleeve and a closing sleeve, the closing sleeve having a collapsible seat; a sand screen spaced from the fracturing sleeve and disposed in a same zone as the frac sleeve, the screen including a screen sleeve having a collapsible seat, the screen seat complementary to a plug that is complementary to the closing sleeve collapsible seat.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 34/00 - Valve arrangements for boreholes or wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A settable device including a radially enlargeable portion, a force retention pathway (between 20 and 42 or between 20 and 160) operably connected to the radially enlargeable portion to maintain a setting force to the radially enlargeable portion, a material disposed within the force retention pathway (between 20 and 42 or between 20 and 160) of the device, the material retaining force when in solid form and disengaging force retention when in fluid form.
Examples of techniques for model-based parameter and state estimation for directional drilling in a wellbore operation are provided. In one example implementation according to aspects of the present disclosure, a computer-implemented method includes receiving, by a processing device, measurement data from the wellbore operation. The method further includes performing, by the processing device, an online estimation of at least one of a parameter to generate an estimated parameter and a state to generate an estimated state, the online estimation based at least in part on the measurement data. The method further includes generating, by the processing device, a control input to control an aspect in the wellbore operation based at least in part on the at least one of the estimated parameter and the estimated state. The method further includes executing a control action based on the control input to control the aspect of the wellbore operation.
A sand control screen system including a housing having an inner diameter, a filtration configuration disposed about the housing, a filtered volume between the housing and the filtration configuration, and a breach feature segregating the filtered volume from the inner diameter.
A method of providing an optimal surfactant blend to improve waterflood efficiency comprises selecting candidate surfactant blends based on one or more of the following: a reservoir condition; information of a crude oil; information of an injection fluid; or information of a formation fluid, each candidate surfactant blends comprising at least two surfactants, one surfactant having a higher relative affinity for the crude oil than for the injection fluid and at least one surfactant having a higher affinity for the injection fluid than for the crude oil; evaluating phase behavior of the candidate surfactant blends to select surfactant blends that form a Winsor III system with the crude oil and the injection fluid at a reservoir temperature; and evaluating the selected surfactant blends in a porous media to select an optimal surfactant blend which achieves at least an additional 10% crude oil recovery after waterflood.
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
An actuation trigger including housing; a piston in operable communication with the housing; a pressure source inlet to the trigger the piston being responsive to source pressure cycles; a first one-direction axial incrementing feature movable with piston movement; a rod movable with the piston and positionally restricted by the one-direction axial incrementing feature, the rod initially being part of a dynamic seal preventing actuation pressure access to a tool actuatable by the actuation pressure.
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
A downhole seal includes a field responsive shape changeable material configured as a layer having a first surface and a second surface, a first field generating electrode disposed in operable communication with the first surface, and a second field generating electrode disposed in operable communication with the second surface.
A substance deposition and backflow preventing arrangement including a housing having a port therein, a sleeve disposed within the housing and positionable to cover or uncover the port, the sleeve having a first seal at one end thereof presenting a first hydraulic dimension and a second seal at another end of the sleeve having a different hydraulic dimension, a biasing member operably connected to the sleeve and to the housing and configured to urge the sleeve to a position covering the port.
A shifting tool includes a body having a longitudinal axis; a structure engaging member supported by the body, the structure engaging member configured to engage and shift a structure within a tubular; and a puncture device supported by the body, the puncture device configured to engage a barrier within a flowbore of the tubular in a direction of the longitudinal axis.
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
54.
METHOD OF IMPROVING PRODUCTION IN STEAM ASSISTED GRAVITY DRAINAGE OPERATIONS
A method of improving production in a steam assisted gravity drainage operation, the method including positioning a tubular system (100) within a borehole, the tubular system (100) including a plurality of inflow control devices (10); injecting steam into a formation (24) to assist in drainage of targeted resources from the formation (24); receiving fluids at an inlet (34) of the inflow control devices (10); and regulating thermal conformance in the formation (24) by choking liquids at the inflow control devices (10) when the liquids have a subcool lower than a predetermined subcool at a selected drawdown pressure.
Systems and sensor elements for indirect monitoring of cumulative damage to downhole components having a sensor body defining an internal cavity, at least one electrical wear element located within the sensor body, wherein a portion of the at least one electrical wear element electrically extends from the internal cavity, through the sensor body, and to an exterior of the sensor body, and an abrasive substance located within the internal cavity, the abrasive substance moveable within the internal cavity to contact and erode material of the at least one electrical wear element, wherein erosion of the at least one electrical wear element causes a resistance of the at least one electrical wear element to increase.
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
56.
INFLOW CONTROL DEVICE AND SYSTEM HAVING INFLOW CONTROL DEVICE
An inflow control device (10) includes a flow device (20, 120, 220, 320, 420, 520) having an inlet (34); an outlet (22); a flow path (42) fluidically connecting the inlet (34) to the outlet (22); and a feature configured to reduce a mass flow rate of liquids to the outlet (22), the liquids having a subcool less than a predetermined subcool for a selected drawdown pressure, lower than a mass flow rate of liquids having a subcool greater than the predetermined subcool at the selected drawdown pressure.
A method of controlling flow in a tubular including developing a pressure in the tubular with an electric submersible pump (ESP), directing a flow of fluid through a flow control device arranged on the tubular downhole of the ESP in response to the pressure, sensing a parameter of the flow of fluid, and adjusting, in real time, a flow parameter of the flow control device with a coil tubing in response to the parameter of the fluid.
Examples of techniques for enhanced reservoir modeling are disclosed. In one example implementation according to aspects of the present disclosure, a computer-implemented method includes estimating, by a processing device, a plurality of reservoir fluid values. The reservoir fluid values includes a density of the fluid, a velocity of the fluid, a pressure differential of the fluid, a temperature of the fluid, a viscosity, and an absolute pressure of the fluid. The method further includes modeling, by the processing device, a mass flow rate based at least in part on the plurality of reservoir fluid values. The method further includes applying the modeled mass flow rate to a wellbore operation.
G06F 15/02 - Digital computers in general; Data processing equipment in general manually operated with input through keyboard and computation using a built-in program, e.g. pocket calculators
59.
DTS PERFORMANCE IMPROVEMENT THROUGH VARIABLE MODE PATH LENGTH AVERAGING
A system and method to determine temperature include an optical fiber and at least two pulse laser sources to transmit light pulses with at least two wavelengths into the optical fiber. The system also includes an optical path length modulator to modulate the optical path length of the optical fiber as the light pulses are transmitted into the optical fiber. At least two photodetectors detect backscatter reflected in the optical fiber, and a processor determines the temperature based on the backscatter.
G01K 11/324 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres using Raman scattering
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 process of manufacturing a free-flowing solid encapsulated drag reducing additive comprises: forming a solid drag reducing additive from one or more C5- 20 olefin monomers; dispersing the solid drag reducing additive in a liquid medium to form a dispersion, the liquid medium comprising an encapsulant and a non-solvent; grinding the solid drag reducing additive in the liquid medium under non-cryogenic grinding conditions to form an encapsulated drag reducing additive in a particulate form; and removing the non-solvent by a drying technique including spray drying, flash drying, or rotating disc drying to form the free-flowing solid encapsulated drag reducing additive.
Treatment of streams containing hydrogen and/or hydrocarbons, and in one non-limiting embodiment refinery distillates, with alkyl carbonates, such as dimethylcarbonate, alone or together with at least one solvent results in reduc¬ tion or removal of hydrogen sulfide (H2S) that is present to give easily removed alkyl sulfides and/or mercaptans. In one non-limiting embodiment, the treatment converts the original hydrogen sulfide into alkyl sulfides and/or mercaptans that can be extracted from the stream with caustic solutions, mercaptan scavengers, solid absorbents such as clay or activated carbon or liquid absorbents such as amine-aldehyde condensates and/or aqueous aldehydes.
An earth-boring tool includes a body, a plurality of blades attached to the body and extending at least to a nose region of the earth-boring tool, a first rotatable cutting structure assembly coupled to the body, and a second rotatable cutting structure assembly coupled to the body. The first rotatable cutting structure assembly includes a first leg and a first rotatable cutting structure rotatably coupled to the first leg. A first cutting profile of the first rotatable cutting structure extends at least from a gage region of the earth-boring tool and at least partially through a cone region of the earth-boring tool. The second rotatable cutting structure assembly includes a second leg and a second rotatable cutting structure rotatably coupled to the second leg. A second cutting profile of the second rotatable cutting structure extends only from the gage region of the earth-boring tool and to an innermost boundary of a nose region of the earth-boring tool.
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
E21B 10/14 - Roller bits combined with non-rolling cutters other than of leading-portion type
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
A method of enhancing oil or gas production comprises injecting into a well penetrating a subterranean formation a pre-flush fluid to increase water wettability of the well, the subterranean formation, a flowline, or a combination comprising at least one of the foregoing; and injecting into the well a foamer composition.
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
64.
METHODS AND SYSTEMS FOR DETECTING RELATIVE POSITIONS OF DOWNHOLE ELEMENTS IN DOWNHOLE OPERATIONS
Methods and systems to initiate downhole operations in a borehole include deploying a first structure at least partially in the borehole, moving a second structure at least partially along the first structure, wherein at least one of the first structure and the second structure is equipped with a sensor and the other of the first and second structure is equipped with a marker detectable by the sensor, detecting a critical event that is related to an interaction of the sensor and the marker, measuring a time-since-critical event, determining a time delay based on the time-since-critical event, transmitting, with a telemetry system, data from the earth's subsurface to the earth's surface indicating that the critical event has been detected, and initiating a downhole operation by using the determined time delay.
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 43/10 - Setting of casings, screens or liners 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
65.
MULTI-CAVITY ALL-GLASS INTERFEROMETRIC SENSOR FOR MEASURING HIGH PRESSURE AND TEMPERATURE
An apparatus for sensing pressure and temperature includes: a hollow glass tube; a first optical fiber having an end disposed into a first end of the tube; a second optical fiber being disposed in a second end of the tube, the second optical fiber having a first solid core section followed by a hollow core section followed by a second solid core section, a first gap formed between the first and second optical fibers, a length of the first solid core section forming a second gap, and a length of the hollow core section forming a third gap; an optical interrogator that transmits light at various wavelengths and measures an intensity of reflected light due to the first gap, second gap, and third gap as a function of frequency to provide interrogation data; and a processor that matches the interrogation data to reference data to estimate the pressure and/or temperature.
G01L 19/00 - MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE - Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
66.
ELECTRICAL DISCHARGE PREVENTION IN BEARING FOR SUBMERSIBLE PUMP MOTOR
A submersible pump electrical motor (17) has a shaft-mounted bearing sleeve (47) between first and second rotor sections (39). An insert sleeve (55) surrounds the bearing sleeve. A non- rotating carrier body (61) surrounds the insert sleeve. First and second seal rings (57a, 57b) are axially spaced apart from each other between an outer diameter of the insert sleeve and an inner diameter of the carrier body. A hole (69) in the carrier body has an inner end at the inner diameter of the carrier body. An electrically conductive coil spring (71) within the hole has an inner end protruding through the inner end of the hole into contact with the outer diameter of the insert sleeve, creating electrical continuity between the insert sleeve and the carrier body.
H02K 11/20 - Structural association of dynamo-electric machines with electric components or with devices for shielding, monitoring or protection for measuring, monitoring, testing, protecting or switching
H02K 5/16 - Means for supporting bearings, e.g. insulating supports or means for fitting bearings in the bearing-shields
A ball drop two stage valve includes a tubular having a body defined by an outer surface and an inner surface that defines a fluid flow path. A stimulation port is formed in the body. The stimulation port extends through the body. At least one flow port is formed in the body longitudinally spaced from the stimulation port. The at least one flow port extends through the body. A first sleeve is slidingly positioned along the fluid flow path in the body. The first sleeve includes a first ball seat and is selectively positionable to selectively block flow through the stimulation port. A second sleeve is slidingly positioned along the fluid flow path in the body. The second sleeve includes a second ball seat and is selectively positionable to selectively block flow through the flow port and the stimulation port.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/00 - Valve arrangements for boreholes or wells
F16K 1/14 - 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 with ball-shaped valve members
68.
EARTH-BORING TOOLS HAVING A GAUGE REGION CONFIGURED FOR REDUCED BIT WALK AND METHOD OF DRILLING WITH SAME
A drill bit comprises a bit body having a longitudinal axis and a blade extending radially outward from the longitudinal axis along a face region and axially along a gauge region. A gauge region includes a cutting element located proximate to an uphole edge of the blade in the gauge region. A remainder of the gauge region is free of cutting elements mounted thereon. A method of drilling a borehole comprises rotating the bit about the longitudinal axis, engaging a formation with cutting elements mounted to the face region, and increasing a lateral force applied substantially perpendicular to the longitudinal axis such that the cutting element engages the formation and such that side cutting exhibited by the tool is initially minimal and substantially constant and subsequently increases in a substantially linear manner with increasing lateral force.
A drill bit for removing subterranean formation material in a borehole comprises a bit body comprising a longitudinal axis, a plurality of blades extending radially outward from the longitudinal axis along a face region of the bit body and extending axially along a gauge region of the bit body, and an insert coupled to at least one blade in the gauge region. The insert comprises an elongated body having an upper surface, a lower surface, and a longitudinal axis extending centrally therethrough and intersecting the upper and lower surfaces. The upper surface comprises a bearing surface for supporting for the drill bit and providing a surface on which the subterranean formation being drilled rubs against the insert without exceeding the compressive strength of the selected formation. The insert is coupled to the blade such that the upper surface thereof extends radially beyond an outer surface of the blade and the lower surface thereof extends radially below the outer surface of the blade.
A drill bit comprises a bit body having a longitudinal axis and a blade extending radially outward from the longitudinal axis along a face region and axially along a gauge region. A gauge region includes a gauge feature and first and second recessed regions extending axially above and below the gauge feature, respectively. The gauge feature comprises an outermost surface extending radially beyond outer surfaces of the blade in the recessed regions. A method of drilling a borehole comprises rotating the bit about the longitudinal axis, engaging a formation with cutting elements mounted to the face region, and increasing a lateral force applied substantially perpendicular to the longitudinal axis such that radially outer surfaces in the gauge region engage the formation and such that side cutting exhibited by the bit is initially minimal and substantially constant and subsequently increases in a substantially linear manner with increasing lateral force.
A flexible device including a plurality of subassemblies, a connector depending from each of the subassemblies, a link connected to the connectors supplying a signal connection between the subassemblies. A resource recovery system including a spoolable conductor including a device disposed in line with the conductor, the device including a plurality of subassemblies, a connector depending from each of the subassemblies, a link connected to the connectors supplying a signal connection between the subassemblies.
H01B 7/04 - Flexible cables, conductors, or cords, e.g. trailing cables
H01R 4/58 - Electrically-conductive connections between two or more conductive members in direct contact, i.e. touching one another; Means for effecting or maintaining such contact; Electrically-conductive connections having two or more spaced connecting locations for conductors and using contact members penetrating insulation characterised by the form or material of the contacting members
H01R 13/58 - Means for relieving strain on wire connection, e.g. cord grip
A system for degrading a structure includes the structure formed of a degradable-on-demand material, an ignitor arranged to transfer heat to the structure; and, a mechanical impactor movable with respect to the structure, wherein the ignitor increases in temperature upon impact of the mechanical impactor into the ignitor, and heat from the ignitor initiates degradation of the structure.
A method and system perform flow characteristic control. The system includes a tube inflow control device (ICD) including a tube input port. The tube ICD conveys fluid along an axial length of a tube of the tube ICD. The axial length of the tube controls a drop in pressure of the fluid between the tube input port and a corresponding tube output port. The system also includes a base pipe with an input port coupled to the tube output port of the tube of the tube ICD, wherein the base pipe is configured to convey the fluid to a surface.
A submersible, electrical well pump assembly comprises a seal section housing for coupling between a motor and a pump of the assembly, the housing having an axis; first and second retainers axially spaced apart and extending toward each other from first and second ends of the housing, respectively, each of the first and second retainers having an outward facing cylindrical wall relative to the axis; a bladder having first and second openings on opposite ends; rigid first and second sleeves bonded to and within the first and second openings, respectively, the first sleeve receiving and secured to the cylindrical wall of the first retainer and the second sleeve receiving and secured to the cylindrical wall of the second retainer; a first retaining ring secured to the cylindrical wall of the first retainer and retaining the first sleeve on the first retainer; and a second retaining ring secured to the cylindrical wall of the second retainer and retaining the second sleeve on the second retainer. The first and second retainers are located within an interior of the bladder.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
A valve including a housing, a body having an aperture radially therethrough fluidly connecting a volume radially inwardly of the body with a volume radially outwardly of the body, a bulkhead sealedly disposed between the body and the housing, the bulkhead having a port therein, a piston extending through the bulkhead and sealed thereto, the piston having a bias end and a carrier end, a biasing member connected to the bias end of the piston, the piston exposed at a carrier end to fluid pressure from the volume radially inwardly of the body, a port closure operably connected to the piston.
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
F16K 31/122 - Operating means; Releasing devices actuated by fluid the fluid acting on a piston
76.
SEAL BLADDER BONDING SLEEVES FOR SUBMERSIBLE WELL PUMP ASSEMBLY
A submersible, electrical well pump assembly comprises a seal section housing for coupling between a motor and a pump of the assembly, the housing having an axis; first and second retainers axially spaced apart and extending toward each other from first and second ends of the housing, respectively, each of the first and second retainers having an outward facing cylindrical wall relative to the axis; a bladder having first and second openings on opposite ends; rigid first and second sleeves bonded to and within the first and second openings, respectively, the first sleeve receiving and secured to the cylindrical wall of the first retainer and the second sleeve receiving and secured to the cylindrical wall of the second retainer; a first set screw that extends through the first sleeve into a mating recess on the cylindrical wall of the first retainer; and a second set screw that extends through the second sleeve into a mating recess on the cylindrical wall of the second retainer. The first and second set screws are exterior of the bladder.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
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
77.
CATIONIC STARCH-BASED ADDITIVES FOR REDUCTION OF FOULING IN WATER COOLERS IN SAGD PRODUCTION SYSTEMS
The present disclosure is directed to a methods and additives for reducing fouling in water coolers in Steam Assisted Gravity Drainage systems (SAGD) in which an additive comprising a cationic starch, either alone or in combination with a water clarifier compound, is introduced into a SAGD system, wherein a lower amount of the additive is used to achieve the same or better results in reducing fouling in the water coolers as compared to an otherwise identical method absent the additive.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
C02F 5/08 - Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents
A high pressure high temperature packer features an actuation assembly of a plurality of rings rotationally locked to a mandrel and initially spaced apart. A pressure actuated piston responsive to tubing pressure pushes the actuation rings together. Spring discs also rotationally locked to the mandrel are between pairs of actuation rings that feature a circumferential protrusion. On application of axial force the protrusion engages a sloping portion of the spring disc and moves the sloping portion toward a more vertical orientation. A corrugated tube surrounds the spring discs with a curled end of each spring disc engaged to an internal tube corrugation. A seal element is on the external corrugations of the tube. The spring discs expand the tube to bring the sealing element and external tube peaks to the borehole wall. Slots in the spring disc allow irregular growth of the tube to conform to surface irregularities.
An embodiment of a system for performing measurements in a downhole environment includes an optical interrogation assembly configured to emit a pulsed optical signal, the pulsed optical signal including a selected wavelength, and an optical fiber configured to be disposed in a borehole in an earth formation and configured to receive the pulsed optical signal, the optical fiber having at least one measurement location disposed therein and configured to at least partially reflect the pulsed optical signal. The optical fiber has a core and a cladding, at least a portion of the core made from at least substantially pure silica, and the optical fiber has a refractive index profile configured to have a zero dispersion wavelength that is greater than the selected wavelength.
A tubular for reservoir fines control includes a body having an outer surface and an inner surface defining a flow path. A plurality of openings are formed in the body connecting the outer surface and the flow path. A material mesh is overlaid onto the outer surface. The material mesh is formed from a material swellable upon exposure to a selected fluid. The material mesh has a selected porosity allowing methane to pass into the flow path while preventing passage of fines.
Evaluating a fluid, including transmitting a light beam through the fluid to a detector while oscillating a path length traveled through the fluid by the light beam at a first frequency of oscillation; measuring a time-dependent intensity of incident light at the detector responsive to an interaction of the light beam with the fluid to produce a time-dependent intensity signal; filtering the time- dependent intensity signal to recover a path-dependent signal oscillating at the first frequency and indicative of an absorbance property of the fluid; and estimating a parameter of interest of the fluid using the path-dependent signal. The time-dependent intensity may be indicative of the true absorbance at multiple wavelengths of the fluid or fluids over the maximum path length difference so as to permit quantification of the percentages of each of these fluids. Filtering may include frequency filtering alone or using a phase- sensitive lock-in amplifier.
G01N 21/31 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry
G01N 21/27 - Colour; Spectral properties, i.e. comparison of effect of material on the light at two or more different wavelengths or wavelength bands using photo-electric detection
82.
DOWNHOLE TOOLS HAVING CONTROLLED DEGRADATION AND METHOD
A downhole assembly includes a matrix material and a unit in contact with the matrix material. The unit includes a core having an energetic material, an activator disposed in direct contact with the core, and at least one layer disposed on the core. The activator includes a triggering system having an igniter and a pre-set timer connected in an electrical circuit. The igniter is inactive in an open condition of the electrical circuit, and, after a preset time period, the pre-set timer closes the electrical circuit and the igniter is activated.
A downhole assembly includes a downhole tool including a degradable-on-demand material including: a matrix material; and, a unit in contact with the matrix material. The unit includes a core including an energetic material configured to generate energy upon activation to facilitate degradation of the downhole tool; and, an activator disposed in contact with the core, the activator including a triggering system having an electrical circuit and an igniter within the electrical circuit, the electrical circuit having an open condition and a closed condition, the electrical circuit configured to be in the closed condition after movement of an object downhole that engages directly or indirectly with the triggering system, and the igniter arranged to ignite the energetic material in the closed condition of the electrical circuit. In the open condition of the electrical circuit the igniter is inactive, and in the closed condition of the electrical circuit the igniter is activated.
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.
Systems and methods for increasing the efficiency of liquefied natural gas (LNG) production, as well as facilitating coproduction of electric power, and compressed natural gas (CNG) are described. The systems and methods facilitate producing an intermediate LNG at a higher temperature, recovering refrigeration from flash gas and boil- off gas from the LNG, using flash-gas and boil-off gas as fuel to generate electric power, and providing LNG, CNG, and electric power to a vehicle fueling facility.
F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen
86.
POLYMER-MODIFIED ASPHALT FOR DRILLING FLUID APPLICATIONS
Polymer-modified asphalt is used in drilling fluids for filtration control, lost circulation control, drill string differential sticking prevention, or wellbore stabilization. The latex modified asphalt provides a mixture of latex-asphalt complex, asphalt, and latex particles that help maintain wellbore stability while drilling into shale formations. The polymer-modified latex is effective for controlling laminated and microfractured shale. Polymers may be functionalized to react with the asphalt to create copolymer modifications of the asphalt for improved performance as drilling fluid additives. The drilling fluids may be water-based or oil-based, or based on an emulsion of oil and water.
A fastening apparatus includes a retaining member comprising a shape memory material configured to transform, responsive to application of a stimulus, from a first solid phase to a second solid phase. The retaining member is disposed within a hole in a body and secured within the hole by phase change which creates an interference fit to secure the retaining member against rotational and axial movement. The hole has a second axial cross-sectional shape. The retaining member has a first axial cross-sectional shape that is preferably either circular or rectangular.
Certain functionalized aldehydes scavengers may be used to at least partially scavenge sulfur-containing contaminants from fluid systems containing hydrocarbons and/or water. The contaminants scavenged or otherwise removed include, but are not necessarily limited to, H2S, mercaptans, and/or sulfides. Suitable scavengers include, but are not necessarily limited to, reaction products of glycolaldehyde with aldehydes; reaction products of glycolaldehyde with a nitrogen-containing reactant (e.g. an amine, a triazine, an imine, an aminal, and/or polyamines); non-nitrogen-containing reaction products of a hydrated aldehyde with certain second aldehydes; reaction products of 1,3, 5-th oxane with hydroxyl-rich compounds (e.g. glyoxal, polyethylene glycol, polypropylene glycol, pentaerythritol, and/or sugars); and reaction products of certain aldehydes with certain phenols; and combinations of these reaction products.
A method of measuring temperatures, includes disposing a carrier in a borehole in an earth formation, the carrier having an optical fiber connected thereto, interrogating the optical fiber with a pulsed optical signal generated by a distributed temperature sensing (DTS) assembly, the pulsed optical signal having a first frequency, and receiving first reflected signals from the optical fiber, estimating an absolute temperature from the reflected signals, interrogating the optical fiber with an at least partially coherent optical signal from a phase sensitive optical time domain reflectometry (?-OTDR) assembly, the at least partially coherent optical signal having a second frequency, and receiving second reflected signals from multiple scattering locations in the optical fiber; estimating a phase difference between the reflected signals, and estimating a temperature change based on the phase difference, and combining the absolute temperature and the temperature change to generate a temperature profile at a location in the borehole.
G01K 11/3206 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres at discrete locations in the fibre, e.g. using Bragg scattering
G01K 11/324 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres using Raman scattering
90.
CONSTRAINED BACKSCATTER GAMMA RAY CASING AND CEMENT INSPECTION TOOL
Methods, systems, devices, and products for estimating at least one parameter of interest of a volume of interest of an earth formation using nuclear radiation based measurements. Logging tools include a limited aperture collimated radiation beam source, detectors, and at least one processor configured to take measurements. The source is configured to emit a beam of radiation radially from the logging tool into an elongated volume of interest outside the wellbore such that the beam penetrates a plurality of zones of the volume of interest. Each zone represents a range of radial depths corresponding to a respective infrastructure component associated with the wellbore, such as nested tubulars. Each detector has a unique angle of detection and is configured to generate measurement information in response to spatially coherent backscattered gamma rays. Each detector is associated with scattering events at one of the plurality of zones.
G01N 23/20 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by using reflection of the radiation by the materials
A CO2 energy storage system includes a storage tank that stores a CO2 slurry, including dry ice and liquid CO2, at CO2 triple point temperature and pressure conditions. The storage system also includes a first pump coupled in flow communication with the storage tank. The first pump is configured to receive the CO2 slurry from the storage tank and to increase a pressure of the CO2 slurry to a pressure above the CO2 triple point pressure. The energy storage system further includes a contactor coupled in flow communication with the first pump. The contactor is configured to receive the high pressure CO2 slurry from the pump and to receive a first flow of gaseous CO2 at a pressure above the CO2 triple point pressure. The gaseous CO2 is contacted and then condensed by the melting dry ice in the slurry to generate liquid CO2
subsea well production system includes a subsea boost pump (33) coupled with a subsea tree conduit (19) having a subsea tree conduit valve (29). boost pump outlet conduit (43) connects between a discharge (41) of the boost pump and an outlet flow line (51). recirculation line (57) extends from the boost pump outlet conduit to the subsea tree conduit. chemical injection line (65) having a chemical source valve (67) extends from a chemical injection source (63) and is connected to the subsea tree conduit at a point between the subsea tree conduit valve and the intake of the boost pump. During production flow boosting, the boost pump pumps well fluid. During chemical injection, the boost pump pumps chemicals into the subsea tree (11).
A frac and gravel packing system including a tubular having a longitudinal axis, a wall defining an interior flowbore, a radial frac port and a radial production port extending through the wall in a first zone of an annular region surrounding the tubular; a screen surrounding the production port, the frac port not covered by the screen; a sleeve system including a sleeve longitudinally shiftable with respect to the longitudinal axis of the tubular, the sleeve configured to cover the frac port in a first positon of the sleeve and uncover the frac port in a second position of the sleeve; and, a return path arranged to permit return fluid from a fracturing operation to exit the first zone of the annular region, wherein the return fluid passes through the screen prior to accessing the return path.
A carbon composite is disclosed, including a plurality of carbon grains, wherein each of the plurality of carbon grains of pores, and a binder disposed between the plurality of carbon grains to bond the plurality of carbon grains, wherein disintegrable binder.
C04B 38/08 - Porous mortars, concrete, artificial stone or ceramic ware; Preparation thereof by adding porous substances
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
ABSTRACT A flow control assembly for borehole use comprises at least one housing having opposed end connections adapted for connection to a tubular string and at least one tortuous path comprising an opposed inlet and an outlet for flow through the housing. The path extends circumferentially substantially around an inner wall of the housing in a zig-zag pattern formed substantially by axially oriented segments connected with circumferentially oriented connecting paths. Date Recue/Date Received 2021-01-05
A system and a method for producing liquefied natural gas are provided. The system includes a refrigeration loop system for providing a cold stream of refrigerant, a supersonic chiller for receiving and chilling a first gaseous natural gas stream to produce a liquefied natural gas liquid and separating the liquefied natural gas liquid from the first gaseous natural gas stream to obtain a second gaseous natural gas stream, and a cold box for receiving the cold stream of refrigerant and the second gaseous natural gas stream and cooling the second gaseous natural gas stream to obtain a liquefied natural gas by heat exchanging between the second gaseous natural gas stream and the cold stream of refrigerant.
F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen
97.
SUPPORTED CATALYST AND METHOD OF USING SAME TO DECREASE THE VISCOSITY OF HEAVY OIL
Asphaltene produced during the production of hydrocarbons in an underground reservoir may be reduced and decomposed by introducing into the underground reservoir a fluid having a catalyst of from about 3 to about 7% Ni with a magnesium oxide support or a catalyst of from about 15 to about 25% tungsten oxide with a zirconium oxide support or a mixture thereof. The viscosity of heavy oil within the underground reservoir is reduced in the presence of the catalyst.
A distributed gas detection system includes solid core fibers, hollow core fibers, and an interrogator device. The solid core fibers are configured to receive light of one or more wavelengths from a light source. The hollow core fibers are disposed in different locations. Each of the hollow core fibers is optically coupled with a different corresponding one of the solid core fibers and configured to receive at least some of the light transmitted through the corresponding solid core fiber. The interrogator device is configured to receive at least some of the light propagating through the solid core fibers and the hollow core fibers. The interrogator device is configured to identify a location of a presence of a gas-of-interest by examining absorption of at least one of the wavelengths of the light in at least one of the hollow core fibers.
Polycrystalline diamond compacts having interstitial diamonds and methods of forming polycrystalline diamond compact shaving interstitial diamonds with a quench cycle are described herein. In one embodiment, a polycrystalline diamond compact includes a substrate and a polycrystalline diamond body attached to the substrate. The polycrystalline diamond body includes a plurality of inter-bonded diamond grains that are attached to one another in an interconnected network of diamond grains and interstitial pockets between the inter-bonded diamond grains, and a plurality of interstitial diamond grains that are positioned in the interstitial pockets. Each of the plurality of interstitial diamond grains are attached to a single diamond grain of the interconnected network of diamond grains or other interstitial diamond grains.
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 35/528 - 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
A method for determining a connectivity of at least one fracture to other fractures in an earth formation includes: obtaining connectivity information for each fracture of interest in the earth formation where the connectivity information for each fracture of interest includes connections with other fractures. The method further includes converting the connectivity information for each fracture of interest into a conjunctive normal form and determining the connectivity of the at least one fracture to other fractures by solving the connectivity information for each fracture of interest in the conjunctive normal form using a Boolean Satisfiability problem solver.
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