Gas lift valves, assemblies, systems, and methods include valves having a valve element for selectively placing a fluid inlet in communication with a fluid outlet, a biasing feature to bias the valve element in one of the open position or the closed position, and a fluid control line actuator for supplying a force to the valve element to overcome the biasing force of the biasing feature and to move the valve element to the other one of the open position or the closed position.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F16K 31/363 - Operating meansReleasing devices actuated by fluid in which fluid from the conduit is constantly supplied to the fluid motor the fluid acting on a piston
Corrosion inhibitor compositions that include silica nanoparticles. The silica nanoparticles can be functionalized with an organosilane. A method includes introducing, adding, or injecting the corrosion inhibitor composition into a fluid to inhibit corrosion on a metal surface that is in contact with the fluid.
C09K 15/30 - Anti-oxidant compositionsCompositions inhibiting chemical change containing organic compounds containing heterocyclic ring with at least one nitrogen atom as ring member
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
Methods and compositions for biofilm removal in industrial applications and systems with prevalent biofilm and/or slime are disclosed. Various industrial processing, such as food and beverage processing, mining pipelines, cooling towers, and energy services applications benefit from the biofilm removal disclosed herein. In particular, the methods and compositions employ alumina nanoparticles alone or in combination with conventional biocides to remove biofilm and/or slime.
A01N 35/02 - Biocides, pest repellants or attractants, or plant growth regulators containing organic compounds containing a carbon atom having two bonds to hetero atoms with at the most one bond to halogen, e.g. aldehyde radical containing aliphatically bound aldehyde or keto groups, or thio-analogues thereofDerivatives thereof, e.g. acetals
A01N 37/16 - Biocides, pest repellants or attractants, or plant growth regulators containing organic compounds containing a carbon atom having three bonds to hetero atoms with at the most two bonds to halogen, e.g. carboxylic acids containing the group Thio-analogues thereof
A01N 57/34 - Biocides, pest repellants or attractants, or plant growth regulators containing organic phosphorus compounds having phosphorus-to-halogen bondsPhosphonium salts
Bearing assemblies, apparatuses, systems, and methods include bearing assemblies having one or more bearing elements in a bearing housing for supporting a shaft extending through at least a portion of the bearing housing. The bearing assembly includes a recirculation line for delivering fluid into the bearing housing at a location separate from a fluid inlet of the bearing housing to at least partially thermally regulate, lubricate, and/or flush the one or more bearing elements during operation of the shaft.
The disclosure provides systems, methods, and compositions for treating a medium. A method may include adding a composition including an additive to the medium. Examples of additives include a dehydrating agent, a carbon dioxide scavenger, an oxygen scavenger, a hydrogen sulfide scavenger, a sulfur oxide scavenger, a nitrogen oxide scavenger, and any combination thereof. A medium may include, for example, hydrogen, and other components, such as an acid and/or an impurity.
C23F 15/00 - Other methods of preventing corrosion or incrustation
B01D 53/46 - Removing components of defined structure
C07C 7/20 - Use of additives, e.g. for stabilisation
C10G 49/00 - Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups , , , , or
C10L 3/00 - Gaseous fuelsNatural gasSynthetic natural gas obtained by processes not covered by subclasses , Liquefied petroleum gas
A formulation for preventing or reducing the effect of impurities contained in the carbon dioxide of a carbon dioxide pipeline. The formulation can include an additive that can adsorb, absorb, react with, complex with, or bind with impurities in the carbon dioxide pipelines to render the impurity in another form, compound, or otherwise unavailable for interaction with the pipeline materials. The additive can be a dehydrating agent, an oxygen scavenger, a hydrogen sulfide scavenger, a sulfur oxides removal agent, a nitrogen oxides removal agent, or combinations thereof.
Compositions and methods for inhibiting corrosion of metal surfaces are disclosed herein. The compositions and methods are particularly useful for inhibiting corrosion of metal surfaces caused by electric currents. The corrosion inhibitor compositions may include one or more of an organic sulfur compound, an organic sulfonic acid amine salt, a dicarboxylic acid diethanolamine salt, a fatty-amine condensate salt, a carboxylic acid-polyamine condensate, and a carboxylic acid. The compositions may include other corrosion inhibitors and/or additional components, such as a solvent, a scale inhibitor, or a biocide, for example.
A plunger ball retention mechanism has an annular ring and inwardly projecting prongs coupled to the annular ring. The plunger ball retention mechanism can couple to the plunger sleeve of a plunger assembly, and the inwardly projecting prongs engage and retain a plunger ball within the plunger sleeve. The plunger ball retention mechanism can have resilient legs with the inwardly projecting prongs thereon, or the inwardly projecting prongs can be portions of a wave spring, or the annular ring can have alternating band and plate portions where the plate portions are connected to the inwardly projecting prongs, or the plunger ball retention mechanism can have a second annular ring and the inwardly projecting prongs are connected to both the annular ring and the second annular ring.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/12 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having free plunger lifting the fluid to the surface
F04B 53/22 - Arrangements for enabling ready assembly or disassembly
9.
PLUNGER WITH PLUNGER BALL RETENTION MECHANISM FOR PLUNGER LIFT APPLICATIONS
A plunger ball retention mechanism has an annular ring and inwardly projecting prongs coupled to the annular ring. The plunger ball retention mechanism can couple to the plunger sleeve of a plunger assembly, and the inwardly projecting prongs engage and retain a plunger ball within the plunger sleeve. The plunger ball retention mechanism can have resilient legs with the inwardly projecting prongs thereon, or the inwardly projecting prongs can be portions of a wave spring, or the annular ring can have alternating band and plate portions where the plate portions are connected to the inwardly projecting prongs, or the plunger ball retention mechanism can have a second annular ring and the inwardly projecting prongs are connected to both the annular ring and the second annular ring.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
F04B 47/00 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
F04B 53/12 - ValvesArrangement of valves arranged in or on pistons
10.
SIMULTANEOUS CONTROL OF SCALE, CORROSION, AND HYDROGEN SULFIDE-RELATED ISSUES USING A SINGLE PRODUCT
The present disclosure relates to methods and compositions for addressing problems that may arise in oil and gas operations. The compositions include multiple components and they may be used in methods of controlling, for example, corrosion, scale, and/or sulfur-containing components in oil and gas operations. A composition may include from about 0.1 wt. % to about 90 wt. % of a solvent, from about 0.1 wt. % to about 90 wt. % of a corrosion inhibitor, from about 0.1 wt. % to about 90 wt. % of a scale inhibitor, and from about 0.1 wt. % to about 90 wt. % of a scavenger.
A sand separator system is utilized in an artificial lift pumping system, where the sand separator system includes a perforated inlet, a separator casing coupled to the perforated inlet, a pump inlet tubing disposed through a central bore of the perforated inlet and forming an annulus with the separator casing, a helical auger component disposed at a distal end of the pump inlet tubing, and a spigot disposed downhole from the helical auger component. The spigot includes a head, a stem extending from the head, and a body portion coupled to a distal end of the stem and having fluid flow passages extending therethrough. The sand separator system is capable of removing at least 55% of the sand particles from a produced hydrocarbon fluid.
Treatment compositions including asphaltenic oil and one or more treatment materials including corrosion inhibitors, scale inhibitors, or a combination thereof are used coat surfaces that are subsequently contacted by one or more corrodents, one or more mineral carbonates, or a combination thereof. The resulting coatings have improved durability when compared to the same treatment materials applied to the same surface in the same amount, but in the absence of the asphaltenic oil.
The present disclosure relates to methods and compositions for addressing problems that may arise in oil and gas operations. The compositions include multiple components and they may be used in methods of controlling, for example, corrosion, scale, and/or sulfur-containing components in oil and gas operations. A composition may include from about 0.1 wt. % to about 90 wt. % of a solvent, from about 0.1 wt. % to about 90 wt. % of a corrosion inhibitor, from about 0.1 wt. % to about 90 wt. % of a scale inhibitor, and from about 0.1 wt. % to about 90 wt. % of a scavenger.
C02F 1/68 - Treatment of water, waste water, or sewage by addition of specified substances, e.g. trace elements, for ameliorating potable water
C02F 5/14 - Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing phosphorus
C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities
14.
Sand Separator System for Artificial Lift Pumping System
A sand separator system is utilized in an artificial lift pumping system, where the sand separator system includes a perforated inlet, a separator casing coupled to the perforated inlet, a pump inlet tubing disposed through a central bore of the perforated inlet and forming an annulus with the separator casing, a helical auger component disposed at a distal end of the pump inlet tubing, and a spigot disposed downhole from the helical auger component. The spigot includes a head, a stem extending from the head, and a body portion coupled to a distal end of the stem and having fluid flow passages extending therethrough. The sand separator system is capable of removing at least 55% of the sand particles from a produced hydrocarbon fluid.
A treatment composition includes a scavenger, an amine, and optionally a booster amine. A treatment composition may be contacted with an H2S rich stream by direct addition of the composition to the H2S rich stream, or by bubbling the H2S rich stream through the composition. The H2S rich stream may be e.g. a produced gas, a biogas, a crude oil, or a produced water. The treated streams have a reduced amount of H2S (and/or another sulfhydryl compound) therein, when compared to the amount of H2S in the stream prior to the treatment. The compositions and methods of treating are characterized by a substantial absence of, or reduction in the amount of precipitate formed thereby, when compared to methods and compositions of the prior art.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A process and gas processing plant configured to contact a produced gas stream with a lean aqueous solution comprising i) water and ii) an amine diol comprising a trisubstituted amine diol, a heterocyclic amine diol, or a combination of trisubstituted amine diol and a heterocyclic amine diol, to produce a treated gas stream comprising methane and a rich aqueous solution comprising the one or more impurities, the amine diol, and the water.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01J 8/02 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with stationary particles, e.g. in fixed beds
C01B 17/04 - Preparation of sulfurPurification from gaseous sulfur compounds including gaseous sulfides
C07C 7/11 - Purification, separation or stabilisation of hydrocarbonsUse of additives by absorption, i.e. purification or separation of gaseous hydrocarbons with the aid of liquids
17.
Underground Pipeline Mapping and Inspection Using Frequency Domain Electromagnetic Device
Underground pipeline mapping and inspection utilizes phase shifts and voltages of electromagnetic signals transmitted to and received from the underground pipeline to determine any displacement of the underground pipeline.
G01B 7/008 - Measuring arrangements characterised by the use of electric or magnetic techniques for measuring coordinates of points using coordinate measuring machines
2222222S in the stream prior to the treatment. The compositions and methods of treating are characterized by a substantial absence of, or reduction in the amount of precipitate formed thereby, when compared to methods and compositions of the prior art.
Compositions and methods for paraffin wax deposit removal and for asphaltene deposit removal from hydrocarbon production wellbores and equipment. The compositions contain a carrier component and a silica nanoparticle component, and the methods utilize the asphaltene or paraffin wax deposit removal compositions to remove paraffin wax deposits or asphaltene deposits from wellbores and/or equipment utilized in hydrocarbon production.
Compositions and methods for inhibiting corrosion of metal surfaces are disclosed herein. The compositions and methods are particularly useful for inhibiting corrosion of metal surfaces caused by electric currents. The corrosion inhibitor compositions may include one or more of an organic sulfur compound, an organic sulfonic acid amine salt, a dicarboxylic acid diethanolamine salt, a fatty-amine condensate salt, a carboxylic acid-polyamine condensate, and a carboxylic acid. The compositions may include other corrosion inhibitors and/or additional components, such as a solvent, a scale inhibitor, or a biocide, for example.
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
C09K 5/20 - Antifreeze additives therefor, e.g. for radiator liquids
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C10G 7/10 - Inhibiting corrosion during distillation
C10G 75/02 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of corrosion inhibitors
A nanoparticle-well treatment additive complex comprising an amine functionalized silica nanoparticle, and a well treatment additive, where the well treatment additive is releasably attached to an amine group of the amine functionalized silica nanoparticle is disclosed. Methods of using the amine functionalized silica nanoparticle is also disclosed.
A controller and process automatically switch operation of the controller between snap operation and throttle operation based on comparing the controller output signal with setpoints for the respective mode of operation. In snap operation, the controller compares the snap cycle times for each snap cycle and the number of snap cycles with snap operation setpoints to determine when to switch the controller from snap operation to throttle operation. In throttle operation, the controller compares the actual controller output signal with a throttle operation setpoint over a threshold throttle time to determine when to switch the controller from throttle operation to snap operation.
F16K 31/18 - Operating meansReleasing devices actuated by fluid actuated by a float
F15B 11/12 - Servomotor systems without provision for follow-up action with only one servomotor providing distinct intermediate positionsServomotor systems without provision for follow-up action with only one servomotor with step-by-step action
F15B 15/22 - Other details for accelerating or decelerating the stroke
Paraffin suppressant - nanoparticulate admixtures are added to petroleum oils, such as crude or refined oils, to obtain treated petroleum oils. The treated petroleum oils obtain a viscosity that is reduced by 5% to 50%, and pour point that is reduced by 0.1 °C to 5 ºC compared to the same petroleum oil treated with the paraffin suppressant in the absence of the nanoparticulate, further where the comparison is made at a temperature between 60 ºC and -4 ºC. The paraffin suppressant - nanoparticulate admixtures also obtain decreased fouling of surfaces by paraffin waxes present in many petroleum oils, when compared to the same petroleum oil treated with the paraffin suppressant in the absence of the nanoparticulate.
C10G 75/04 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of antifouling agents
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C10L 10/04 - Use of additives to fuels or fires for particular purposes for minimising corrosion or incrustation
A formulation for preventing or reducing the effect of impurities contained in the carbon dioxide of a carbon dioxide pipeline. The formulation can include an additive that can adsorb, absorb, react with, complex with, or bind with impurities in the carbon dioxide pipelines to render the impurity in another form, compound, or otherwise unavailable for interaction with the pipeline materials. The additive can be a dehydrating agent, an oxygen scavenger, a hydrogen sulfide scavenger, a sulfur oxides removal agent, a nitrogen oxides removal agent, or combinations thereof.
09 - Scientific and electric apparatus and instruments
41 - Education, entertainment, sporting and cultural services
42 - Scientific, technological and industrial services, research and design
Goods & Services
Controlling, measuring, and testing equipment for use in
monitoring, managing, assessing, and optimizing compressors,
engines, rotating equipment and reciprocating machinery;
electronic devices for monitoring and analyzing compressors,
engines, rotating equipment, and reciprocating machinery;
diagnostic instruments for compressors, engines, rotating
equipment, and reciprocating machinery. Training and instruction in the nature of the operation of
electronic devices and diagnostic instruments for monitoring
and analyzing compressors, engines, rotating equipment, and
reciprocating machinery and distribution of training
material in connection therewith. Providing sensors and temporary use of online
non-downloadable software for collection, analysis,
monitoring, and reporting of data relating to the
performance and use conditions of engines, compressors,
rotating equipment, and reciprocating machinery for
scientific purposes.
26.
ASPHALTENE AND PARAFFIN WAX DEPOSIT REMOVAL WITH SILICA NANOPARTICLES
Compositions and methods for paraffin wax deposit removal and for asphaltene deposit removal from hydrocarbon production wellbores and equipment. The compositions contain a carrier component and a silica nanoparticle component, and the methods utilize the asphaltene or paraffin wax deposit removal compositions to remove paraffin wax deposits or asphaltene deposits from wellbores and/or equipment utilized in hydrocarbon production.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
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
27.
AUTOMATICALLY SWITCHING A CONTROLLER BETWEEN SNAP OPERATION AND THROTTLE OPERATION
A controller and process automatically switch operation of the controller between snap operation and throttle operation based on comparing the controller output signal with setpoints for the respective mode of operation. In snap operation, the controller compares the snap cycle times for each snap cycle and the number of snap cycles with snap operation setpoints to determine when to switch the controller from snap operation to throttle operation. In throttle operation, the controller compares the actual controller output signal with a throttle operation setpoint over a threshold throttle time to determine when to switch the controller from throttle operation to snap operation.
A nanoparticle-well treatment additive complex comprising an amine functionalized silica nanoparticle, and a well treatment additive, where the well treatment additive is releasably attached to an amine group of the amine functionalized silica nanoparticle is disclosed. Methods of using the amine functionalized silica nanoparticle is also disclosed.
01 - Chemical and biological materials for industrial, scientific and agricultural use
09 - Scientific and electric apparatus and instruments
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Chemical additives for use in the manufacture of corrosion
inhibitors for industrial water systems; chemicals for use
in purification of water; chemicals for use in water
treatment; chemical preparations for use in industry. Scientific instrumentation for measuring and monitoring
water chemistry in water systems; scientific instrumentation
for measuring and monitoring water chemistry and system
performance in water systems; measuring devices, namely,
fluorometers; water testing instrumentation for monitoring
and detecting contamination; electronic apparatus and
instruments for controlling, adjusting and testing of drives
and motors; electronic controllers for monitoring and
measuring chemicals in industrial water systems; electronic
controllers for adjusting operating parameters in industrial
water systems and regulating the flow of water. Consulting services in the field of water treatment. Providing on-line non-downloadable software for operating
fluorometers and electronic controllers and recording and
processing and transmitting data; monitoring of water
quality; technical quality monitoring services of water
conditions.
01 - Chemical and biological materials for industrial, scientific and agricultural use
09 - Scientific and electric apparatus and instruments
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Chemical additives for use in the manufacture of corrosion
inhibitors in industrial water systems; chemicals for use in
purification of water; chemicals for use in water treatment;
chemical preparations for use in industry. Scientific instrumentation for measuring and monitoring
water chemistry in water systems; scientific instrumentation
for measuring and monitoring water chemistry and system
performance in water systems; measuring devices, namely,
fluorometers; water testing instrumentation for monitoring
and detecting contamination; electronic apparatus and
instruments for controlling, adjusting and testing of drives
and motors; electronic controllers for monitoring and
measuring chemicals in industrial water systems; electronic
controllers for adjusting operating parameters in industrial
water systems and regulating the flow of water. Consulting services in the field of water treatment. Providing on-line non-downloadable software for operating
fluorometers and electronic controllers and recording and
processing and transmitting data; monitoring of water
quality; technical quality monitoring services of water
conditions.
31.
SYNERGISTIC EFFECTS OF NANOPARTICLES AND SURFACTANTS FOR WATER INJECTIVITY IMPROVEMENT
Compositions of nanoparticles and surfactants for improved water injectivity are disclosed. More specifically, synergistic combination of nanoparticles, including amine functionalized colloidal nanoparticles and surfactants, provides enhanced water injectivity and increased oil production. Methods of using are also disclosed.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
32.
SYNERGISTIC EFFECTS OF NANOPARTICLES AND SURFACTANTS FOR GAS LIFT FLOW IMPROVEMENT
Compositions of nanoparticles and surfactants for enhanced gas lift through increased foaming heights and foam stability are disclosed. More specifically, synergistic combination of nanoparticles, including amine functionalized colloidal nanoparticles and surfactants, provides enhanced gas lift and increased oil production are disclosed. Methods of using are also disclosed.
Metal-based ceramic composite coatings and related devices, assemblies, and methods include monocrystalline superhard particles dispersed in a metal matrix disposed on at least one wear surface of a component of an oil and gas well assembly, system, or device.
Sensor systems and methods for downhole pumping systems include a sensor subsystem for detecting movement of at least one component of the downhole pumping system. The sensor subsystem includes an axial motion sensor to be coupled to the at least one component of the downhole pumping system and to detect axial movement of the at least one component of the downhole pumping system and a rotational sensor to be coupled to the at least one component of the downhole pumping system and to detect rotational movement of the at least one component of the downhole pumping system.
E21B 47/009 - Monitoring of walking-beam pump systems
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/092 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting magnetic anomalies
35.
COMPOSITIONS AND METHODS FOR CONTROLLING SLUDGE BED PROPERTIES AND IMPROVING LIME SOFTENING PROCESS EFFICIENCY
The present disclosure relates to compositions including coagulants, testing methods and devices, and methods used in connection with lime softening processes, such as warm or hot lime softening processes. The compositions, devices, and methods disclosed herein may be used to improve sludge bed properties in lime softening processes, such as warm lime softening process or hot lime softening processes.
The present disclosure relates to compositions including coagulants, testing methods and devices, and methods used in connection with lime softening processes, such as warm or hot lime softening processes. The compositions, devices, and methods disclosed herein may be used to improve sludge bed properties in lime softening processes, such as warm lime softening process or hot lime softening processes.
C02F 1/00 - Treatment of water, waste water, or sewage
C02F 9/00 - Multistage treatment of water, waste water or sewage
C02F 1/52 - Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
C02F 1/66 - Treatment of water, waste water, or sewage by neutralisationTreatment of water, waste water, or sewage pH adjustment
C02F 5/02 - Softening water by precipitation of the hardness
C02F 5/06 - Softening water by precipitation of the hardness using calcium compounds
C02F 5/12 - Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing nitrogen
A pressure-equalization holder is provided with a laboratory-scale reactor for measuring material deposition with a quartz crystal microbalance assembly. The pressure-equalization holder allows a process liquid from an interior of the laboratory-scale reactor to contact a liquid-facing crystal surface of a crystal of a quartz crystal microbalance assembly. The pressure-equalization holder also allows an inert fluid to contact an inert fluid-facing crystal surface of the crystal, where the inert fluid is at the same pressure as the process liquid.
G01B 11/06 - Measuring arrangements characterised by the use of optical techniques for measuring length, width, or thickness for measuring thickness
G01B 17/02 - Measuring arrangements characterised by the use of infrasonic, sonic, or ultrasonic vibrations for measuring thickness
G01N 17/00 - Investigating resistance of materials to the weather, to corrosion or to light
G01N 21/94 - Investigating contamination, e.g. dust
G01N 29/036 - Analysing fluids by measuring frequency or resonance of acoustic waves
G01G 3/16 - Weighing apparatus characterised by the use of elastically-deformable members, e.g. spring balances wherein the weighing element is in the form of a solid body stressed by pressure or tension during weighing measuring variations of frequency of oscillations of the body
A pressure-equalization holder is provided with a laboratory-scale reactor for measuring material deposition with a quartz crystal microbalance assembly. The pressure-equalization holder allows a process liquid from an interior of the laboratory-scale reactor to contact a liquid-facing crystal surface of a crystal of a quartz crystal microbalance assembly. The pressure-equalization holder also allows an inert fluid to contact an inert fluid-facing crystal surface of the crystal, where the inert fluid is at the same pressure as the process liquid.
G01N 29/036 - Analysing fluids by measuring frequency or resonance of acoustic waves
G01N 29/22 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic wavesVisualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object Details
39.
CORROSION INHIBITOR COMPOSITIONS AND METHODS OF USING THE SAME
The disclosure provides a composition including a corrosion inhibitor compound and an iron chelating agent. The composition may be used in a method of inhibiting corrosion of a metal surface. The method includes adding the composition to an aqueous system that includes the metal surface. The composition may be applied to the metal surface, for example, using batch treatment techniques.
Methods of treating drilled or fractured subterranean formations include the steps of packing at least a portion of the subterranean formation with a packing composition to form a packed subterranean formation; and applying a sealing composition to the packed subterranean formation to form a treated subterranean formation. Alternatively, a packing composition is mixed with a sealing composition to form a reactive composition, and the reactive composition is applied to at least a portion of the subterranean formation to form a treated subterranean formation. The reactive compositions cure within the treated subterranean formations to provide sealed subterranean formations.
E21B 33/138 - Plastering the borehole wallInjecting into the formation
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
41.
COMPOSITIONS AND METHODS FOR FLUID LOSS CONTROL IN A SUBTERRANEAN FORMATION
Methods of treating drilled or fractured subterranean formations include the steps of packing at least a portion of the subterranean formation with a packing composition to form a packed subterranean formation; and applying a sealing composition to the packed subterranean formation to form a treated subterranean formation. Alternatively, a packing composition is mixed with a sealing composition to form a reactive composition, and the reactive composition is applied to at least a portion of the subterranean formation to form a treated subterranean formation. The reactive compositions cure within the treated subterranean formations to provide sealed subterranean formations.
C09K 8/504 - Compositions based on water or polar solvents
C09K 8/506 - Compositions based on water or polar solvents containing organic compounds
C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C09K 8/514 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
E21B 33/138 - Plastering the borehole wallInjecting into the formation
42.
IN-LINE ELECTROCHEMICAL CONVERTER FOR IN-SITU GENERATION OF ACTIVE CHEMICALS
The disclosure pertains to methods and systems for converting inactive chemicals into active chemicals in-situ for treating oil and gas pipelines, other industrial systems, or sanitizing surfaces. A method of treating an oil and gas pipeline is disclosed. The method may include feeding an inactive additive through a first conduit and into a second conduit, wherein the second conduit is in fluid communication with the first conduit and the oil and gas pipeline. The method also includes converting the inactive additive into an active additive within the second conduit and introducing the active additive into the oil and gas pipeline.
C02F 1/46 - Treatment of water, waste water, or sewage by electrochemical methods
C02F 1/467 - Treatment of water, waste water, or sewage by electrochemical methods by electrolysis by electrochemical disinfection
C02F 5/12 - Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing nitrogen
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C10G 75/00 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
43.
CORROSION INHIBITOR COMPOSITIONS AND METHODS OF INHIBITING CORROSION
The disclosure provides a composition including a corrosion inhibitor compound and a synergist. The composition may be used in a method of inhibiting corrosion of a metal surface. The method includes adding the composition to an aqueous medium that includes the metal surface and/or adding the compound and/or polymer directly to the metal surface. The composition may be applied to the metal surface, for example, using batch treatment and/or continuous injection. Examples of synergists include a lignin polymer, polyvinyl alcohol, cellulose, gelatin, or a combination thereof.
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
44.
IN-LINE ELECTROCHEMICAL CONVERTER FOR IN-SITU GENERATION OF ACTIVE CHEMICALS
The disclosure pertains to methods and systems for converting inactive chemicals into active chemicals in-situ for treating oil and gas pipelines, other industrial systems, or sanitizing surfaces. A method of treating an oil and gas pipeline is disclosed. The method may include feeding an inactive additive through a first conduit and into a second conduit, wherein the second conduit is in fluid communication with the first conduit and the oil and gas pipeline. The method also includes converting the inactive additive into an active additive within the second conduit and introducing the active additive into the oil and gas pipeline.
Compositions and methods for inhibiting corrosion of metal surfaces are disclosed herein. Also disclosed are metal surfaces coated or partially coated with the compounds, compositions, and/or components of the present disclosure. The corrosion inhibitor compositions may include corrosion inhibitor compounds having the structure of Formula I. The compositions may include other corrosion inhibitors and/or additional components, such as a solvent, a scale inhibitor, or a biocide.
The disclosure provides a composition including a corrosion inhibitor compound and a synergist. The composition may be used in a method of inhibiting corrosion of a metal surface. The method includes adding the composition to an aqueous medium that includes the metal surface and/or adding the compound and/or polymer directly to the metal surface. The composition may be applied to the metal surface, for example, using batch treatment and/or continuous injection. Examples of synergists include a lignin polymer, polyvinyl alcohol, cellulose, gelatin, or a combination thereof.
Compositions and methods for inhibiting corrosion of metal surfaces are disclosed herein. Also disclosed are metal surfaces coated or partially coated with the compounds, compositions, and/or components of the present disclosure. The corrosion inhibitor compositions may include corrosion inhibitor compounds having the structure of Formula I. The compositions may include other corrosion inhibitors and/or additional components, such as a solvent, a scale inhibitor, or a biocide.
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
C02F 5/10 - Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
09 - Scientific and electric apparatus and instruments
41 - Education, entertainment, sporting and cultural services
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Controlling, measuring, and testing equipment for use in monitoring, managing, assessing, and optimizing compressors, engines, rotating equipment and reciprocating machinery; electronic devices for monitoring and analyzing compressors, engines, rotating equipment, and reciprocating machinery; diagnostic instruments for compressors, engines, rotating equipment, and reciprocating machinery; (1) Training and instruction in the nature of the operation of electronic devices and diagnostic instruments for monitoring and analyzing compressors, engines, rotating equipment, and reciprocating machinery and distribution of training material in connection therewith;
(2) Collection, analysis, monitoring, and reporting of data using software and sensors for the performance and use conditions of engines, compressors, rotating equipment, and reciprocating machinery for scientific purposes
42 - Scientific, technological and industrial services, research and design
Goods & Services
Providing a website featuring on-line non-downloadable software that enables users to maintain and diagnose machinery, namely, to detect and measure performance in machines in the field of machinery having compressor cylinders; Software as a service (SAAS) services featuring software for maintenance and diagnosis of machinery, namely, for detecting and measuring performance in machines in the field of machinery having compressor cylinders; Monitoring of machinery, namely, monitoring the performance of machines and machinery diagnostic services in the field of industrial machinery equipment, namely, the remote monitoring and diagnostic services of machinery having compressor cylinders for quality control purposes
01 - Chemical and biological materials for industrial, scientific and agricultural use
09 - Scientific and electric apparatus and instruments
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Chemical additives for prevention of scale, corrosion and microbiological growth in industrial water systems; chemicals for use in purification of water; chemicals for use in water treatment; chemical preparations for use in industry
(2) Scientific instrumentation for measuring and monitoring water chemistry in water systems; scientific instrumentation for measuring and monitoring water chemistry and system performance in water systems; measuring devices, namely, fluorometers; water testing instrumentation for monitoring and detecting contamination; electronic apparatus and instruments for controlling, adjusting and testing of drives and motors; electronic controllers for monitoring and measuring chemicals in industrial water systems; electronic controllers for adjusting operating parameters in industrial water systems and regulating the flow of water (1) Consulting services in the field of water treatment
(2) Providing on-line non-downloadable software for operating fluorometers and electronic controllers and recording and processing and transmitting data; monitoring of water quality; technical quality monitoring services of water conditions
51.
NANOBUBBLE CONTAINING COMPOSITIONS AND METHODS OF USE
A nanobubble containing composition is disclosed that includes a plurality of gas-filled nanobubbles and a nanobubble stabilizer. The nanobubble containing composition can contain a continuous phase and a discontinuous phase dispersed in the continuous phase. Methods of using the nanobubble containing composition are also disclosed.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
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
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
Valve assemblies and related pumps, plungers, lift assemblies, and methods may include an insert disposed in an internal flow path of a plunger. The insert includes protrusions, each individually extending into the internal flow path of the plunger and converging at an apex of the insert to define a cage in which the restriction element is configured to move axially through the internal flow path.
Hydrate inhibitor and corrosion inhibitor composition are disclosed and include from about 10 wt-% to about 99.9 wt-% of an anti-agglomerant low dose hydrate inhibitor (AA-LDHI), wherein the AA-LDHI is a zwitterionic compound or a cationic ammonium compound; from about 0.01 wt-% to about 50 wt-% of a corrosion inhibitor, and at least one additional functional ingredient, solvent, or a combination thereof. Methods for inhibiting corrosion and formation of gas hydrate agglomerants in a fluid are disclosed and include contacting the fluid with a hydrate inhibitor and corrosion inhibitor composition or contacting the fluid with an AA-LDHI, wherein the AA-LDHI is a zwitterionic compound or a cationic ammonium compound, and a corrosion inhibitor, wherein the AA-LDHI and corrosion inhibitor are provided at a weight ratio of about 1:0.001 to about 1:1, and wherein the composition inhibits general and localized corrosion and formation of gas hydrate agglomerants in the fluid.
Technologies for specialty chemical development and testing include devices and methods for normalizing historical specialty chemical test results and training a chemical composition predictor to predict chemical components of a formulation given a test condition and a normalized performance indicator based on the normalized test results. The specialty chemical may be a corrosion indicator, and the normalized performance indicator may be corrosion rate. The devices and methods may predict a predicted composition with the trained chemical composition predictor. the devices and methods may filter the normalized test results based on the predicted composition and train a formulation optimization predictor to predict a normalized performance indicator based on the filtered test results. The devices and methods may generate multiple candidate chemical formulations based on the predicted composition and predict a normalized performance indicator for each candidate chemical formulation with the trained formulation optimization predictor.
Technologies for specialty chemical development and testing include devices and methods for normalizing historical specialty chemical test results and training a chemical composition predictor to predict chemical components of a formulation given a test condition and a normalized performance indicator based on the normalized test results. The specialty chemical may be a corrosion indicator, and the normalized performance indicator may be corrosion rate. The devices and methods may predict a predicted composition with the trained chemical composition predictor. the devices and methods may filter the normalized test results based on the predicted composition and train a formulation optimization predictor to predict a normalized performance indicator based on the filtered test results. The devices and methods may generate multiple candidate chemical formulations based on the predicted composition and predict a normalized performance indicator for each candidate chemical formulation with the trained formulation optimization predictor.
G16C 20/30 - Prediction of properties of chemical compounds, compositions or mixtures
G16C 60/00 - Computational materials science, i.e. ICT specially adapted for investigating the physical or chemical properties of materials or phenomena associated with their design, synthesis, processing, characterisation or utilisation
G16C 20/70 - Machine learning, data mining or chemometrics
56.
COMPOSITIONS AND METHODS FOR IMPROVING THERMAL AND BRINE STABILITY OF NANOPARTICLES
Amine functionalized nanoparticles comprising a core-shell nanoparticle morphology comprising a trialkoxyorganosilane coated nanoparticle core and an amine functionalized group on the surface of the nanoparticle as a shell are disclosed, wherein the nanoparticle has an average particle size from about 1 nm to about 1000 nm. Methods and applications of use of the amine functionalized nanoparticles and compositions comprising the amine functionalized nanoparticles dispersed in an aqueous medium are also disclosed.
C09K 8/92 - Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
Downhole centrifugal pumps and related components and methods may include stationary diffusers housing impellers where the stationary diffusers have radial sidewalls defining a radially outer portion of each of the stationary diffusers. Coupling members may be defined on the stationary diffusers to at least partially transfer a rotational force through the centrifugal pump.
Downhole centrifugal pumps and related components and methods may include diffusers housing impellers where the diffusers have radial sidewalls defining a radially outer portion of each of the diffusers. Coupling members may extend between and engage with the diffusers.
Diamond coated rotational, reciprocating, and corrosion
resistant machine parts to improve wear resistance in
artificial lift systems in the oil and gas sector.
61.
SOLVENTS FOR CONTAINER APPLICATION OF OILFIELD PRODUCTS
A water-soluble container including a treatment chemical is provided. The treatment chemical may be, for example, an organic sulfur compound, an imidazoline, a carboxylic acid, a fatty acid amine condensate, a substituted fatty acid ester, a substituted aromatic amine, a phosphoric acid ester, a quaternary ammonium compound, a compound having multiple positive charges, or any combination of these chemicals. The water-soluble container may include, for example, cellulose, polyvinyl alcohol, gelatin, or any combination of these materials.
A water-soluble container including a treatment chemical is provided. The treatment chemical may be, for example, an organic sulfur compound, an imidazoline, a carboxylic acid, a fatty acid amine condensate, a substituted fatty acid ester, a substituted aromatic amine, a phosphoric acid ester, a quaternary ammonium compound, a compound having multiple positive charges, or any combination of these chemicals. The water-soluble container may include, for example, cellulose, polyvinyl alcohol, gelatin, or any combination of these materials.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
Downhole centrifugal pumps and related components and methods may include diffusers housing impellers and a rotational shaft passing through the impellers to impart rotation to the impellers. Bearings are positioned within at least some of the diffusers to support the rotational shaft during the rotation of the impellers. Coupling pins may be positioned between and engage with the bearings and the at least some of the diffusers to at least partially secure each of the bearings to one of the at least some of the diffusers.
Methods of recovering a hydrocarbon from a subterranean reservoir include combining a solvent with 0.1 ppm to 10,000 ppm by weight of one or more sulfonate polymers to form a treatment composition; contacting the treatment composition with a crude oil disposed within the reservoir to form a treated crude oil; and collecting the treated crude oil from the reservoir. The sulfonate polymers are selected from poly(methylene naphthalene sulfonate) homopolymers and copolymers, branched or crosslinked polymers having pendant benzenesulfonate moieties, and any combination thereof. The treatment compositions are suitable for umbilical injection into a subsea reservoir. The treated crude oils obtain a 30% - 99% reduction in asphaltene fouling compared to an untreated crude oil obtained from the same reservoir.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
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
Asphaltene inhibiting compositions include a mixture of a sulfonate material with an amine condensate. The sulfonate material includes one or more sulfonate salts, one or more sulfonate polymers, or a mixture thereof; and the amine condensate includes a reaction product of one or more organic acids with one or more organic compounds having at least two amine groups. The asphaltene inhibiting compositions can form stable injection solutions suitable for use in subsea umbilicals. Combinations of crude oil with the asphaltene inhibiting compositions undergo reduced, or inhibited, asphaltene deposition onto liquid-solid interfaces when compared to asphaltene deposition of the same crude oil in the absence of the composition. The asphaltene inhibiting compositions are particularly effective for inhibiting deposition of coke-like asphaltenes.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
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
66.
COMPOSITIONS AND METHODS FOR CONTROLLING ASPHALTENE DEPOSITION
Methods of recovering a hydrocarbon from a subterranean reservoir include combining a solvent with 0.1 ppm to 10,000 ppm by weight of one or more sulfonate polymers to form a treatment composition; contacting the treatment composition with a crude oil disposed within the reservoir to form a treated crude oil; and collecting the treated crude oil from the reservoir. The sulfonate polymers are selected from poly(methylene naphthalene sulfonate) homopolymers and copolymers, branched or crosslinked polymers having pendant benzenesulfonate moieties, and any combination thereof. The treatment compositions are suitable for umbilical injection into a subsea reservoir. The treated crude oils obtain a 30%-99% reduction in asphaltene fouling compared to an untreated crude oil obtained from the same reservoir.
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
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
67.
ELUTION SYSTEMS FOR TREATMENT OF SUBTERRANEAN RESERVOIRS
Methods for treating a producing wellbore of a subterranean reservoir include obtaining a side stream flow of a produced fluid from a production tube of the wellbore at a location above the surface of the earth; providing an eluting contact of the side stream flow of produced fluid with a treatment material to form a side stream flow of treated produced fluid; and directing the side stream flow of treated produced fluid into the wellbore at a point below the surface of the earth. Apparatuses suitable for carrying out the methods include an elution device fluidly connected to a side stream of produced fluid flowing above the surface of the earth and situated to direct the side stream toward the elution device to provide an eluting contact of the produced fluid with a treatment material disposed in the elution device, then direct the treated produced fluid into the wellbore.
Asphaltene inhibiting compositions include a mixture of a sulfonate material with an amine condensate. The sulfonate material includes one or more sulfonate salts, one or more sulfonate polymers, or a mixture thereof; and the amine condensate includes a reaction product of one or more organic acids with one or more organic compounds having at least two amine groups. The asphaltene inhibiting compositions can form stable injection solutions suitable for use in subsea umbilicals. Combinations of crude oil with the asphaltene inhibiting compositions undergo reduced, or inhibited, asphaltene deposition onto liquid-solid interfaces when compared to asphaltene deposition of the same crude oil in the absence of the composition. The asphaltene inhibiting compositions are particularly effective for inhibiting deposition of coke-like asphaltenes.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
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
Technologies for multiphase hydrate fraction modeling include devices and methods for receiving an initial feed composition of a constant volume cell and a time series of pressure data and temperature data for the cell during a test procedure. The devices and methods include determining a non-equilibrium hydrate fraction for the constant volume cell based on the time series of pressure data and temperature data, predicting one or more phase components of the constant volume cell based on the non-equilibrium hydrate fraction. The devices and methods may include displaying gas composition in the constant volume cell over the time series based on the prediction.
Compositions and methods for mitigating organic and inorganic contaminants in produced water prior to lime softening in a steam-assisted gravity drainage facilities (SAGD) are disclosed. In particular methods wherein starch-based coagulants and/or flocculants are added to produced water prior to warm lime softening in a SAGD facility are disclosed.
Compositions and methods for mitigating organic and inorganic contaminants in produced water prior to lime softening in a steam-assisted gravity drainage facilities (SAGD) are disclosed. In particular methods wherein starch-based coagulants and/or flocculants are added to produced water prior to warm lime softening in a SAGD facility are disclosed.
Compositions and methods for inhibiting corrosion of metal surfaces and reducing levels of hydrogen sulfide are disclosed herein. A composition may include a nitrogen-containing alicyclic compound and/or a thio-containing compound. The nitrogen-containing alicyclic compound and the thio-containing compound may be added to a medium in contact with a metal surface and/or they may be added directly to a metal surface. Other components may be added as well, such as a biocide and/or a scale inhibitor.
Technologies for multiphase hydrate fraction modeling include devices and methods for receiving an initial feed composition of a constant volume cell and a time series of pressure data and temperature data for the cell during a test procedure. The devices and methods include determining a non-equilibrium hydrate fraction for the constant volume cell based on the time series of pressure data and temperature data, predicting one or more phase components of the constant volume cell based on the non-equilibrium hydrate fraction. The devices and methods may include displaying gas composition in the constant volume cell over the time series based on the prediction.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
Managing gas interference in a downhole pump, such as for liquid hydrocarbon well production, is accomplished by monitoring pump operational data indicating liquid pump fillage values, determining from indicative patterns in the monitored data, possibly observed over a number of pump strokes, whether a gas interference condition exists, and in response to determining that the gas interference condition exists, increasing a normal pump speed to a higher speed. In response to determining that the gas interference condition does not exist, a normal pump speed may be resumed.
Managing gas interference in a downhole pump, such as for liquid hydrocarbon well production, is accomplished by monitoring pump operational data indicating liquid pump fillage values, determining from indicative patterns in the monitored data, possibly observed over a number of pump strokes, whether a gas interference condition exists, and in response to determining that the gas interference condition exists, increasing a normal pump speed to a higher speed. In response to determining that the gas interference condition does not exist, a normal pump speed may be resumed.
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
F04B 49/20 - Control of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for in, or of interest apart from, groups by changing the driving speed
78.
CORROSION INHIBITOR COMPOSITIONS AND METHODS OF USING THE COMPOSITIONS TO INHIBIT CORROSION
Compositions and methods for inhibiting corrosion of metal surfaces and reducing levels of hydrogen sulfide are disclosed herein. A composition may include a nitrogen-containing alicyclic compound and/or a thio-containing compound. The nitrogen-containing alicyclic compound and the thio-containing compound may be added to a medium in contact with a metal surface and/or they may be added directly to a metal surface. Other components may be added as well, such as a biocide and/or a scale inhibitor.
C02F 5/12 - Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances containing nitrogen
Disclosed are alkyl lactone-derived hydroxyamides and alkyl lactone-derived hydroxyesters used in compositions and methods for inhibiting natural gas hydrate agglomerates. The alkyl lactone-derived hydroxyamides and alkyl lactone-derived hydroxyesters are reaction products of an alkyl lactone and an amine, and an alkyl lactone and an alcohol, respectively.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C07C 237/10 - Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by amino groups having the carbon atoms of the carboxamide groups bound to acyclic carbon atoms of the carbon skeleton the carbon skeleton being acyclic and saturated having the nitrogen atom of at least one of the carboxamide groups bound to an acyclic carbon atom of a hydrocarbon radical substituted by nitrogen atoms not being part of nitro or nitroso groups
C07D 223/04 - Heterocyclic compounds containing seven-membered rings having one nitrogen atom as the only ring hetero atom not condensed with other rings with only hydrogen atoms, halogen atoms, hydrocarbon or substituted hydrocarbon radicals, directly attached to ring carbon atoms
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
80.
METHODS FOR MITIGATING PRODUCED WATER COOLER FOULING
Methods for mitigating produced water cooler fouling in steam assisted gravity drainage (SAGD) systems are disclosed. In addition, methods for reducing fouling in SAGD systems with a produced water cooler by injecting a production fluid with a reverse emulsion with a demulsifier prior to phase separation of the production fluid, where the separation of water from the reverse emulsion is at a temperature above about 100°C to form a separated water phase for subsequent steam generation, are disclosed.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
C10G 33/04 - De-watering or demulsification of hydrocarbon oils with chemical means
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
81.
CORROSION INHIBITOR COMPOSITIONS AND METHODS OF USING THE COMPOSITIONS TO INHIBIT CORROSION
Compositions and methods for inhibiting corrosion of metal surfaces are disclosed herein. Also disclosed are methods of manufacturing the corrosion inhibitor compositions. A corrosion inhibitor composition may include an ether diamine compound. A corrosion inhibitor composition may include a sulfur-containing compound. A corrosion inhibitor composition may include an additional component and optionally a solvent.
A gas lift injection packer assembly, a gas lift injection system that includes the assembly, and methods utilizing the assembly and system are disclosed. The gas lift injection packer assembly includes a top sub, a packer coupled to the top sub, a bottom sub coupled to the packer, a sleeve disposed within the top sub, the packer, and the bottom sub. The inner diameters of the components of the gas lift injection packer assembly form a continuous passage from end-to-end of the gas lift injection packer assembly such that a downhole tool can be moved through the gas lift injection packer assembly while the gas lift injection packer assembly is sealed in a wellbore. A gas inlet port of the top sub can be formed such that an inner wall of the gas inlet port is the housing for a check valve.
Methods and compositions utilize a sand obtained by combining a dirty sand with a chemical additive, where the combination decreases the water drain time through the sand compared to the sand without the chemical additive. The decrease of water drain time reduces the amount of time to dry the sand after a wash, and when using the sand for proppant, promotes conductivity of fluid through the sand when the sand is in a fracture of a subterranean formation.
Methods for mitigating produced water cooler fouling in steam assisted gravity drainage (SAGD) systems are disclosed. In addition, methods for reducing fouling in SAGD systems with a produced water cooler by injecting a production fluid with a reverse emulsion with a demulsifier prior to phase separation of the production fluid, where the separation of water from the reverse emulsion is at a temperature above about 100° C. to form a separated water phase for subsequent steam generation, are disclosed.
Methods for mitigating produced water cooler fouling in steam assisted gravity drainage (SAGD) systems are disclosed. In addition, methods for reducing fouling in SAGD systems with a produced water cooler by injecting a production fluid with a reverse emulsion with a demulsifier prior to phase separation of the production fluid, where the separation of water from the reverse emulsion is at a temperature above about 100°C to form a separated water phase for subsequent steam generation, are disclosed.
C02F 1/68 - Treatment of water, waste water, or sewage by addition of specified substances, e.g. trace elements, for ameliorating potable water
C08L 63/00 - Compositions of epoxy resinsCompositions of derivatives of epoxy resins
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
C10G 33/04 - De-watering or demulsification of hydrocarbon oils with chemical means
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
Compositions and methods for inhibiting corrosion of metal surfaces are disclosed herein. Also disclosed are methods of manufacturing the corrosion inhibitor compositions. A corrosion inhibitor composition may include an ether diamine compound. A corrosion inhibitor composition may include a sulfur-containing compound. A corrosion inhibitor composition may include an additional component and optionally a solvent.
A gas lift injection packer assembly, a gas lift injection system that includes the assembly, and methods utilizing the assembly and system. The gas lift injection packer assembly includes a top sub, a packer coupled to the top sub, a bottom sub coupled to the packer, a sleeve disposed within the top sub, the packer, and the bottom sub. The inner diameters of the components of the gas lift injection packer assembly form a continuous passage from end-to-end of the gas lift injection packer assembly such that a downhole tool can be moved through the gas lift injection packer assembly while the gas lift injection packer assembly is sealed in a wellbore. A gas inlet port of the top sub can be formed such that an inner wall of the gas inlet port is the housing for a check valve.
Methods and compositions utilize a sand obtained by combining a dirty sand with a chemical additive, where the combination decreases the water drain time through the sand compared to the sand without the chemical additive. The decrease of water drain time reduces the amount of time to dry the sand after a wash, and when using the sand for proppant, promotes conductivity of fluid through the sand when the sand is in a fracture of a subterranean formation.
Methods of treating a produced water having one or more water soluble organic compounds (WSO) dispersed therein include mixing the produced water with 1 ppm to 50,000 ppm by weight of an adsorbent particulate to form a slurry; and separating a purified produced water from the slurry, wherein the purified produced fluid includes a lower concentration of one or more WSO than the produced fluid, wherein WSO is the fraction of the dissolved and dispersed hexane extractable compounds in the produced water that does not flash off at 85ºC, and adsorbs onto silica gel.
C02F 1/28 - Treatment of water, waste water, or sewage by sorption
B01J 20/20 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising free carbonSolid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising carbon obtained by carbonising processes
B01J 20/28 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof characterised by their form or physical properties
C02F 1/00 - Treatment of water, waste water, or sewage
C02F 1/24 - Treatment of water, waste water, or sewage by flotation
C02F 1/38 - Treatment of water, waste water, or sewage by centrifugal separation
C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
C02F 1/52 - Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities
C02F 103/36 - Nature of the water, waste water, sewage or sludge to be treated from the chemical industry not provided for in groups from the manufacture of organic compounds
(1) Diamond coated rotational, reciprocating, and corrosion resistant machine parts to improve wear resistance in artificial lift systems in the oil and gas sector
Methods of treating a produced water having one or more water soluble organic compounds (WSO) dispersed therein include mixing the produced water with 1 ppm to 50,000 ppm by weight of an adsorbent particulate to form a slurry; and separating a purified produced water from the slurry, wherein the purified produced fluid includes a lower concentration of one or more WSO than the produced fluid, wherein WSO is the fraction of the dissolved and dispersed hexane extractable compounds in the produced water that does not flash off at 85° C., and adsorbs onto silica gel.
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
B01J 20/10 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising silica or silicate
B01J 20/28 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof characterised by their form or physical properties
Treatment compositions including asphaltenic oil and one or more treatment materials including corrosion inhibitors, scale inhibitors, or a combination thereof are used coat surfaces that are subsequently contacted by one or more corrodents, one or more mineral carbonates, or a combination thereof. The resulting coatings have improved durability when compared to the same treatment materials applied to the same surface in the same amount, but in the absence of the asphaltenic oil.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 41/02 - Equipment or details not covered by groups in situ inhibition of corrosion in boreholes or wells
93.
TREATMENT COMPOSITIONS INCLUDING FUNCTIONALIZED PARTICULATE
222S when compared to the corrosion inhibition performance of the same corrosion inhibitor coating in the absence of the functionalized particulate. The coatings including functionalized particulate are usefully applied to one or more interior and/or exterior surfaces of containments, separators, conduits, and other equipment, such well string completion components, that are contacted by fluids containing corrodents.
Treatment compositions include a mixture of a corrosion inhibitor and a functionalized particulate in a solvent. The functionalized particulate includes both epoxy and amine groups. Surfaces coated with the treatment composition have improved corrosion inhibition performance, and/or greater duration of corrosion inhibition performance with respect to corrodents such as CO2 and H2S when compared to the corrosion inhibition performance of the same corrosion inhibitor coating in the absence of the functionalized particulate. The coatings including functionalized particulate are usefully applied to one or more interior and/or exterior surfaces of containments, separators, conduits, and other equipment, such well string completion components, that are contacted by fluids containing corrodents.
Treatment compositions including asphaltenic oil and one or more treatment materials including corrosion inhibitors, scale inhibitors, or a combination thereof are used coat surfaces that are subsequently contacted by one or more corrodents, one or more mineral carbonates, or a combination thereof. The resulting coatings have improved durability when compared to the same treatment materials applied to the same surface in the same amount, but in the absence of the asphaltenic oil.
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
E21B 41/02 - Equipment or details not covered by groups in situ inhibition of corrosion in boreholes or wells
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
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
96.
APPARATUSES AND METHODS OF PUMPING SHEAR-SENSITIVE FLUIDS
Apparatus and method for pumping emulsion polymers and other shear-sensitive fluids comprising: a first reservoir (10) for a first fluid; a second reservoir (20) for a second fluid which is a shear-sensitive fluid; a first vessel (30) with a first chamber (16) and a second chamber (26), and a movable partition (34) therebetween; a high pressure pump (12) in communication with the first reservoir (10) and the first chamber (16) through a first fill line (14) and a first chamber inlet valve (17); a low pressure pump (22) in communication with the second reservoir (20) and the second chamber (26) through a second fill line (24) and a second chamber inlet valve (27); a first recycle line (32) in communication with the first chamber (16) and the first reservoir (10) through a first chamber outlet valve (18); and a second exit line (34) in communication with the second chamber (26) through a second chamber outlet valve (34); and a switching circuit capable of controlling the first chamber inlet valve (17), the first chamber outlet valve (18), the second chamber inlet valve (27), and the second chamber outlet valve (28).
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
F04B 9/103 - Piston machines or pumps characterised by the driving or driven means to or from their working members the means being fluid the fluid being liquid having only one pumping chamber
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
F04B 23/02 - Pumping installations or systems having reservoirs
Apparatuses and methods for pumping emulsion polymers and other sensitive fluids that eliminates the high shear that can be destructive to the fluid have been developed. These methods can be used to deliver emulsion polymers continuously from topside through umbilical to subsea produced fluids flowlines to increase oil production and/or flow of gas/oil by reducing friction loss due to turbulent flow in the flowlines.
F17D 1/17 - Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity by mixing with another liquid
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
98.
APPARATUSES AND METHODS OF PUMPING SHEAR-SENSITIVE FLUIDS
Apparatus and method for pumping emulsion polymers and other shear-sensitive fluids comprising: a first reservoir (10) for a first fluid; a second reservoir (20) for a second fluid which is a shear-sensitive fluid; a first vessel (30) with a first chamber (16) and a second chamber (26), and a movable partition (34) therebetween; a high pressure pump (12) in communication with the first reservoir (10) and the first chamber (16) through a first fill line (14) and a first chamber inlet valve (17); a low pressure pump (22) in communication with the second reservoir (20) and the second chamber (26) through a second fill line (24) and a second chamber inlet valve (27); a first recycle line (32) in communication with the first chamber (16) and the first reservoir (10) through a first chamber outlet valve (18); and a second exit line (34) in communication with the second chamber (26) through a second chamber outlet valve (34); and a switching circuit capable of controlling the first chamber inlet valve (17), the first chamber outlet valve (18), the second chamber inlet valve (27), and the second chamber outlet valve (28).
F04B 9/103 - Piston machines or pumps characterised by the driving or driven means to or from their working members the means being fluid the fluid being liquid having only one pumping chamber
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
F04B 23/02 - Pumping installations or systems having reservoirs
09 - Scientific and electric apparatus and instruments
41 - Education, entertainment, sporting and cultural services
42 - Scientific, technological and industrial services, research and design
Goods & Services
Controlling, measuring, and testing equipment for use in monitoring, managing, assessing, and optimizing compressors, engines, rotating equipment and reciprocating machinery; electronic devices for monitoring and analyzing compressors, engines, rotating equipment, and reciprocating machinery; diagnostic instruments for compressors, engines, rotating equipment, and reciprocating machinery Training and instruction in the nature of the operation of electronic devices and diagnostic instruments for monitoring and analyzing compressors, engines, rotating equipment, and reciprocating machinery and distribution of training material in connection therewith Collection, analysis, monitoring, and reporting of data using software and sensors for the performance and use conditions of engines, compressors, rotating equipment, and reciprocating machinery for scientific purposes
100.
TREATMENT COMPOSITIONS INCLUDING ALUMINA PARTICULATE
Treatment compositions including a corrosion inhibitor having an amine group and a particulate including Al 2 O 3 are coated on a surface to impart corrosion inhibition thereto. The coated surfaces have improved duration of corrosion inhibition performance with respect to corrodents such as CO 2 and H 2 S when compared to the corrosion inhibition performance of the same corrosion inhibitor coating but in the absence of the particulate including Al 2 O 3 . The coatings are usefully applied to one or more interior and/or exterior surfaces of containments, conduits, and other equipment, such well string completion components, that are contacted by produced fluids containing corrodents.
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
E21B 41/02 - Equipment or details not covered by groups in situ inhibition of corrosion in boreholes or wells
