Electrical separators employing detection of conductive fluid excursions are described herein. A separator of this type has a separator, comprising a separation vessel; an electric field assembly extending a first distance within the separation vessel in a first direction of a density-based separation force; a plurality of detector electrodes extending a second distance within the separation vessel in the first direction; one or more power units; and one or more circuits electrically coupling the electric field electrodes and the detector electrodes with the one or more power units.
A system for measuring a microorganism concentration and applying a biocide includes an injection pump in fluid communication with at least one biocide tank and a fluid conduit in fluid communication with a wellbore, microorganism sensor in fluid communication with the fluid conduit and configured to determine a microorganism concentration of fluid in the fluid conduit, and a biocide controller in operable communication with the injection pump and the microorganism sensor. The biocide controller is configured to determine a biocide dosage to apply to the fluid based on the microorganism concentration, and control an operation of the injection pump to apply the biocide dosage to the fluid. Related methods and biocide application systems are also disclosed.
A system for measuring a microorganism concentration and applying a biocide includes an injection pump in fluid communication with at least one biocide tank and a fluid conduit in fluid communication with a wellbore, microorganism sensor in fluid communication with the fluid conduit and configured to determine a microorganism concentration of fluid in the fluid conduit, and a biocide controller in operable communication with the injection pump and the microorganism sensor. The biocide controller is configured to determine a biocide dosage to apply to the fluid based on the microorganism concentration, and control an operation of the injection pump to apply the biocide dosage to the fluid. Related methods and biocide application systems are also disclosed.
C12Q 1/04 - Determining presence or kind of microorganismUse of selective media for testing antibiotics or bacteriocidesCompositions containing a chemical indicator therefor
G01N 33/48 - Biological material, e.g. blood, urineHaemocytometers
4.
METHOD AND APPARATUS FOR GREENHOUSE GAS EMISSION MANAGEMENT
A method includes receiving an indication of an emission plume traveling along a first direction. The method also includes determining a cross-section of the emission plume, wherein the cross-section is substantially perpendicular to the first direction. Further, the method includes determining a travel path for an optical detector to obtain optical measurements along the cross-section, wherein the travel path extends in a second direction along the cross-section, and the optical detector is configured to obtain the optical measurements in a third direction crosswise to the travel path.
A system for local power generation to power equipment at a well site which may include a gas line configured to receive a gas flow from a well. The system may also include a turbine comprising an inlet and an outlet and configured to receive the gas flow from the gas line at the inlet and generate power based on a pressure differential between the inlet and the outlet.
A wellhead system includes a wellhead housing and a hanger configured to support a casing within the wellhead housing. The hanger includes one or more passages formed through the hanger. The wellhead system also includes a seal assembly configured to move relative to the hanger to selectively enable a flow of fluid across the hanger via the one or more passages. The hanger, the seal assembly, and a lock ring may be run together into the wellhead housing.
A wellhead includes a wellhead housing, a hanger configured to support a casing, and multiple passages formed in or along the wellhead housing, through the hanger, external to the wellhead housing, or any combination thereof. The wellhead also includes at least one movable component configured to move relative to the multiple passages to selectively enable a flow of fluid via the multiple passages from an annular space defined between the wellhead housing and the hanger below the hanger to a portion of a bore within the wellhead housing above the hanger.
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
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 23/04 - 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 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
8.
SYSTEMS AND METHODS FOR CEMENTING CASING AND SEALING A HANGER IN A WELLHEAD HOUSING
A wellhead includes a wellhead housing, a hanger configured to support a casing, and multiple passages formed in or along the wellhead housing, through the hanger, external to the wellhead housing, or any combination thereof. The wellhead also includes at least one movable component configured to move relative to the multiple passages to selectively enable a flow of fluid via the multiple passages from an annular space defined between the wellhead housing and the hanger below the hanger to a portion of a bore within the wellhead housing above the hanger.
A wellhead system includes a wellhead housing and a hanger configured to support a casing within the wellhead housing. The hanger includes one or more passages formed through the hanger. The wellhead system also includes a seal assembly configured to move relative to the hanger to selectively enable a flow of fluid across the hanger via the one or more passages. The hanger, the seal assembly, and a lock ring may be run together into the wellhead housing.
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
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 23/04 - 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 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
10.
LOCAL POWER GENERATION FOR GAS TO LIQUID CONVERSION AND FLARE REDUCTION SYSTEMS AND METHODS
A system for local power generation to power equipment at a well site which may include a gas line configured to receive a gas flow from a well. The system may also include a turbine comprising an inlet and an outlet and configured to receive the gas flow from the gas line at the inlet and generate power based on a pressure differential between the inlet and the outlet.
Systems and methods presented herein generally relate to greenhouse gas emission management and, more particularly, to a greenhouse gas emission management workflow to perform greenhouse gas detection sensor placement or greenhouse gas leak detection. For example, the system and method enable improved gas sensor arrangements within an oil and gas worksite. In another example, the system and method enable the prediction of a location and a leak rate of a gas leak within an oil and gas production facility based on measurements collected by gas leak sensors disposed within the facility and prevailing wind information.
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
G01M 3/16 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point using electric detection means
G01W 1/10 - Devices for predicting weather conditions
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
12.
FIBER OPTICS WITH NUMERICAL SIMULATORS FOR PIPELINE LEAK QUANTIFICATION
A system includes a fiber optic cable configured to detect one or more first parameters of a leak event along a fluid conduit, and one or more sensors configured to measure one or more second parameters of a fluid flow along the fluid conduit. The system also includes a controller including a processor, a memory, and instructions stored on the memory and executable by the processor to: detect the one or more first parameters of the leak event via the fiber optic cable, measure the one or more second parameters of the fluid flow via the one or more sensors, input the one or more first parameters and the one or more second parameters into a model configured to simulate operation with the fluid conduit, and output leak information corresponding to the leak event via execution of the model.
G01M 3/04 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point
G01M 3/38 - Investigating fluid tightness of structures by using light
G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
G01D 21/02 - Measuring two or more variables by means not covered by a single other subclass
Systems and methods presented herein generally relate to a method that includes providing one or more recommendations relating to greenhouse gas emission reduction goals to a customer. The method also includes receiving one or more greenhouse gas emission reduction goals from the customer. The one or more greenhouse gas emission reduction goals relate to a reduction in greenhouse gas emissions at one or more oil and gas worksites associated with the customer. The method also includes determining a greenhouse gas emission reduction plan to reduce the greenhouse gas emissions at the one or more oil and gas worksites to achieve the one or more greenhouse gas emission reduction goals. The method further includes performing work to implement the greenhouse gas emission reduction plan. The method also includes collecting and analyzing greenhouse gas emission measurements to ensure that the one or more greenhouse gas emission reduction goals have been achieved by the greenhouse gas emission reduction plan.
A system includes a fiber optic cable configured to detect one or more first parameters of a leak event along a fluid conduit, and one or more sensors configured to measure one or more second parameters of a fluid flow along the fluid conduit. The system also includes a controller including a processor, a memory, and instructions stored on the memory and executable by the processor to: detect the one or more first parameters of the leak event via the fiber optic cable, measure the one or more second parameters of the fluid flow via the one or more sensors, input the one or more first parameters and the one or more second parameters into a model configured to simulate operation with the fluid conduit, and output leak information corresponding to the leak event via execution of the model.
G01M 3/04 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point
G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
G01M 3/24 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point using infrasonic, sonic, or ultrasonic vibrations
A MEG recovery process is described, in which a MEG stream is processed by performing a divalent treatment to reduce dissolved divalent cations in the portion of the stream; performing a sulfate treatment to reduce dissolved sulfate ions in the stream, the sulfate treatment comprising adding an underdose of one or more calcium halides, one or more lower calcium carboxylates, or a mixture thereof to a treatment stream; and precipitating calcium sulfate from the treatment stream; performing a solids removal treatment to reduce solids in the stream; and returning the treated stream, depleted in divalent cations, sulfate ions, and solids, to the MEG recovery process.
A ball valve assembly includes a ball configured to rotate between an open position and a closed position. The ball valve assembly also includes an annular seat configured to engage the ball and a rotatable ring having a first engagement feature. In addition, the ball valve assembly includes a non-rotatable ring positioned adjacent to the rotatable ring. The ball valve assembly also includes a drive plate non-rotatably coupled to the ball. The drive plate includes a second engagement feature, and the second engagement feature is configured to engage the first engagement feature to drive the rotatable ring to rotate in response to rotation of the drive plate. Furthermore, the ball valve assembly includes a bearing element configured to drive the rotatable ring and the non-rotatable ring away from one another to compress the annular seat against the ball in response to rotation of the rotatable ring.
F16K 5/20 - Special arrangements for separating the sealing faces or for pressing them together for plugs with spherical surfaces
F16K 5/06 - Taps or cocks comprising only cut-off apparatus having at least one of the sealing faces shaped as a more or less complete surface of a solid of revolution, the opening and closing movement being predominantly rotary with plugs having spherical surfacesPackings therefor
F16K 27/06 - Construction of housingsUse of materials therefor of taps or cocks
17.
ASPHALTENE INHIBITION AND/OR DISPERSION IN PETROLEUM FLUIDS
Compositions may include an asphaltene dispersant that is the product of a reaction between a polysaccharide having at least two sugar subunits and one or more fatty acid reagents, and a petroleum fluid produced from a subterranean formation and containing asphaltenes therein. The asphaltene dispersant may have a molecular weight of at least 4000 Da. Compositions may further include an aromatic solvent. Methods may include contacting a hydrocarbon fluid with an asphaltene dispersant dissolved in an aromatic solvent, wherein the asphaltene dispersant is the product of the reaction of a polysaccharide and one or more fatty acid reagents. Methods may also include contacting a hydrocarbon fluid with an asphaltene, wherein the asphaltene dispersant is the product of the reaction of a polysaccharide and one or more fatty acid reagents and has a molecular weight of at least 4000 Da.
Embodiments described herein provide corrosion inhibitors that use hyperbranched polymer molecules functionalized with amino carboxylic acids, epoxides, and/or long chain fatty acids, or combinations thereof. Nitrogen atoms in such molecules can be quaternized to increase water solubility if needed. Such hyperbranched polymer corrosion inhibitors can be used in all stages of oil and gas operation.
Systems and methods for carbon capture using produced water are provided. One such system includes a direct air capture (DAC) subsystem. The DAC subsystem includes an air inlet configured to receive a flow of air comprising carbon dioxide, a water inlet configured to receive a flow of produced water from a production system. The DAC subsystem also includes one or more air-water contactors configured to contact the flow of air with the flow of produced water to dissolve carbon dioxide from the air into the produced water to produce a treated air and a water output, where the water output includes a carbon rich aqueous solution including dissolved carbon dioxide, carbonic acid, carbonate anions, bicarbonate anions, or a combination thereof.
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
Embodiments described herein provide corrosion inhibitors that use hyperbranched polymer molecules functionalized with amino carboxylic acids, epoxides, and/or long chain fatty acids, or combinations thereof. Nitrogen atoms in such molecules can be quaternized to increase water solubility if needed. Such hyperbranched polymer corrosion inhibitors can be used in all stages of oil and gas operation.
A method includes coupling a damper to a cable and a load, and moving the damper, the cable, the load, or a combination thereof. In response to the movement, slack is introduced into the cable, and the slack is suddenly released, which exerts a tensile load on the damper and the cable. The damper is configured to dampen the tensile load exerted on the cable.
A resource extraction and/or injection system includes an injection system configured to direct a fluid into a reservoir via a well for storage in the reservoir to facilitate extraction of resources from the reservoir and a generator configured to convert potential energy of the fluid into electrical energy via flow of the fluid through the well.
A resource extraction system includes a compressor and turbine system configured to extract a resource from a reservoir via a well and a control system configured to operate the resource extraction system in a first operating mode in response to determining a pressure of the resource exceeds a threshold pressure to operate the compressor and turbine system as a turbine and reduce the pressure of the resource and generate electrical energy in the first operating mode. The control system is also configured to operate the resource extraction system in a second operating mode in response to determining the pressure of the resource is below the threshold pressure to operate the compressor and turbine system as a compressor and increase the pressure of the resource in the second operating mode.
A modular fracturing system including a fracturing fluid manifold and a skid apparatus coupled in fluid communication with the fracturing fluid manifold and only one fracturing tree. The skid apparatus can include an inlet coupled to the fracturing fluid manifold, a single outlet coupled to the one fracturing tree via a fluid conduit, and a valve between the inlet and the single outlet to control flow of fracturing fluid from the fracturing fluid manifold through the skid apparatus to the one fracturing tree.
A surface well fracturing system having fluid conduits connected to surface fracturing equipment with quick connect systems is provided. In one embodiment, a fracturing system includes a frac pump, a frac supply manifold, and a fracturing fluid conduit connected to route fracturing fluid between the frac pump and the frac supply manifold. The fracturing fluid conduit is connected to the frac pump or to the frac supply manifold by a quick connect apparatus, which includes a segmented clamp having multiple clamp segments mounted on a shared support. Additional systems, devices, and methods are also disclosed.
The disclosure provides for a valve including a surface movably engaged with another surface. A coating is on the surface and is characterized by: a CoF of less than 0.1; a hardness in excess of 1,200 HVN; impermeability to liquids at pressures ranging from 15 and 20,000 psi; a surface finish of 63 or less; and a thickness ranging from 0.5 to 20 mils. The disclosure provides for material constructions including a continuous phase, including a transition metal, and a discontinuous phase, including a solid dry lubricant. The disclosure also provides for a method of depositing a coating that includes depositing a first layer of a coating onto a surface using electroplating, electroless plating, thermal spraying, or cladding, and then depositing a second layer of the coating onto a surface of the first layer using sputtering, ion beam, plasma enhanced chemical vapor deposition, cathodic arc, or chemical vapor deposition.
C10N 30/00 - Specified physical or chemical property which is improved by the additive characterising the lubricating composition, e.g. multifunctional additives
C10N 30/12 - Inhibition of corrosion, e.g. anti-rust agents, anti-corrosives
C10N 50/00 - Form in which the lubricant is applied to the material being lubricated
C10N 50/08 - Form in which the lubricant is applied to the material being lubricated solid
C23C 28/00 - Coating for obtaining at least two superposed coatings either by methods not provided for in a single one of main groups , or by combinations of methods provided for in subclasses and
C23C 28/02 - Coating for obtaining at least two superposed coatings either by methods not provided for in a single one of main groups , or by combinations of methods provided for in subclasses and only coatings of metallic material
F16K 5/06 - Taps or cocks comprising only cut-off apparatus having at least one of the sealing faces shaped as a more or less complete surface of a solid of revolution, the opening and closing movement being predominantly rotary with plugs having spherical surfacesPackings therefor
An apparatus includes a sensor for sensing pressure, temperature, or another physical parameter at a wellhead assembly or other oilfield component. In one embodiment, an apparatus includes a wellhead body and a branch assembly coupled to the wellhead body such that a bore of the branch assembly is in fluid communication with an interior of the wellhead body through an access passage of the wellhead body. The branch assembly includes a penetration extending outwardly from the bore to an exterior surface of the branch assembly that is radially outward of the bore, and a sensor is installed in the penetration of the branch assembly. Additional systems, devices, and methods are also disclosed.
A system includes a processor and a memory, accessible by the processor, the memory storing instructions that, when executed by the processor, cause the processor to receive, from a density sensor with an integrated temperature probe, first data indicative of a density of an aqueous liquid flowing through a line, and second data indicative of a temperature of the aqueous liquid flowing through the line, receive, from an electromagnetic sensor, third data indicative of a dielectric property of the aqueous liquid flowing through the line, apply an interpretation model to the first data, the second data and the third data to determine a concentration of hydrate inhibitor of the aqueous liquid flowing through the line based on the density, the temperature and the dielectric property of the aqueous liquid flowing through the line, and generate an indication of the concentration of hydrate inhibitor of the aqueous liquid flowing through the line.
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
A seal assembly for sealing between a casing string and a wellhead housing is provided. In one embodiment, a system includes a seal assembly (80) received within a bore (48) of a wellhead housing (20). The seal assembly can include an elongate body (82), an inner seal (86) positioned within the elongate body to seal between the elongate body and a well casing (46), and a setting ring (88) positioned within the elongate body to apply a setting load to the inner seal to energize the inner seal between the elongate body and the well casing. The system can also include a running tool (100) having an end received within the elongate body of the seal assembly, and a piston setting assembly (110) including a piston (112) and a push sleeve (114) for setting the inner seal via the setting ring. Additional systems, devices, and methods are also disclosed.
A wellhead system includes a first casing hanger configured to support a first casing. The wellhead system also includes a second casing hanger configured to support a second casing within the first casing. The wellhead system further includes a seal assembly configured to provide an annular seal between the first casing hanger and the second casing hanger. The seal assembly is configured to move between a first position in which the seal assembly enables a flow of fluid across the second casing hanger and a second position in which the seal assembly blocks the flow of fluid across the second casing hanger.
A wellhead includes a wellhead housing, a passage formed in or along the wellhead housing, and a hanger with a seal assembly. The seal assembly is configured to provide an annular seal across an annular space between the hanger and the wellhead housing, and the hanger is configured to move within the wellhead housing to selectively enable a flow of fluid across the seal assembly via the passage.
A wellhead includes a wellhead housing, a passage formed in or along the wellhead housing, and a hanger configured to support a casing. The wellhead also includes a seal assembly configured to provide an annular seal across an annular space between the hanger and the wellhead housing. In operation, a movable seal component or the seal assembly is configured to move relative to the passage to selectively enable a flow of fluid across the seal assembly via the passage.
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
33.
SULFIDE AND PROCESS CHEMICAL TREATMENT OF PRODUCTION FLUIDS USING METAL OXIDE PARTICLES
Methods and apparatus for treatment of hydrocarbon streams containing hydrogen sulfide are described herein. The hydrocarbon stream is contacted with metal oxide particles loaded with a hydrogen sulfide scavenger and a production aid. The hydrocarbon sulfide scavenger removes hydrogen sulfide from the hydrocarbon stream and the production aid moves from the metal oxide particles into the hydrocarbon stream to facilitate subsequent processing.
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
An adapter clamp system for use with a housing of a wellhead includes a clamp assembly configured to apply radial compression to a housing of a wellhead. The adapter clamp system also includes an adapter configured to actuate the clamp assembly to apply the radial compression to the housing of the wellhead, wherein the adapter is configured to couple the housing of the wellhead to another structure stacked axially relative to the wellhead.
A choke gate valve includes a housing that defines a fluid bore and a gate with multiple throttling orifices. The gate is configured to move within the housing between a first throttle position in which the gate extends across the fluid bore to position a first throttling orifice of the multiple throttling orifices in the fluid bore to throttle a fluid flow through the fluid bore and a second throttle position in which the gate extends across the fluid bore to position a second throttling orifice of the multiple throttling orifices in the fluid bore to throttle the fluid flow through the fluid bore.
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 3/314 - Forms or constructions of slidesAttachment of the slide to the spindle
F16K 47/04 - Means in valves for absorbing fluid energy for decreasing pressure, the throttle being incorporated in the closure member
A monitoring system includes a first transducer component configured to couple to a running tool that is configured to place an insert into a housing and a second transducer component configured to couple to the housing. One of the first transducer component or the second transducer component is configured to emit acoustic waves, and the other one of the first transducer component or the second transducer component is configured to output sensor signals indicative of a received portion of the acoustic waves. The monitoring system also includes one or more processors configured to determine that the insert is in a landed position in the housing based on the sensor signals.
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
Vaporizers that have high fluid mixing are disclosed herein. Such vaporizer has a vessel with a circular cross-section; a heating pathway with a first conduit for withdrawing fluid from the vessel coupled to a heater and a second conduit for returning fluid to the vessel; and a fluid distributor disposed within the vessel and fluidly coupled to the second conduit, the fluid distributor having a conduit to flow fluid into the vessel in an entry direction; and a circular distribution plate having a central inlet coupled to the conduit and a plurality of peripheral outlets, the circular distribution plate defining a plane, wherein each peripheral outlet is fluidly coupled to the central inlet by a flow path that curves in an azimuthal direction, and each peripheral outlet is shaped to direct fluid flow out of the distributor away from the plane of the circular distribution plate along the entry direction.
Embodiments described herein provide materials and methods for scavenging mercaptans in a hydrocarbon production context. Mercaptan scavenging methods include adding a branched or hyperbranched polyacrylate material to a target material comprising hydrocarbon and mercaptans; and reacting the polyacrylate material with the mercaptans to form a thioether.
C10L 3/10 - Working-up natural gas or synthetic natural gas
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
39.
SULFONYL AZIDE COMPOSITION FOR SULFUR SCAVENGING IN OILFIELD OPERATIONS
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
40.
BICARBONATE REMOVAL FROM MONOETHYLENE GLYCOL-WATER STREAMS
Systems and processes for the removal of bicarbonate from MEG-water-salt streams are provided. Such systems and processes remove dissolved bicarbonate from MEG-water-salt streams by addition of divalent cations and hydroxide anions.
A system includes a hanger with a radially-outer surface with a hanger surface texture. The system also includes a sensor configured to detect vibrations induced by the hanger surface texture as the hanger moves through a housing of a wellhead. The system further includes a controller configured to receive signals indicative of the vibrations from the sensor and to process the signals to determine a position of the hanger within the housing of the wellhead.
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
E21B 19/24 - Guiding or centralising devices for drilling rods or pipes
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
42.
SYSTEM AND PROCESS FOR REMOVAL OF ORGANIC CARBOXYLATES FROM MONO ETHYLENE GLYCOL (MEG) WATER STREAMS BY ACIDIFICATION AND VAPORIZATION UNDER VACUUM
A system and method for removing organic carboxylates from a mono ethylene glycol (“MEG”) stream includes a reaction vessel; means for cooling and diluting the MEG stream being routed to the reaction vessel; means for acidifying the cooled and diluted MEG stream during its residence time within the reaction vessel; and means for removing an acetic-rich overhead stream from the reaction vessel. The acidification of the cooled and diluted MEG stream occurs under a vacuum. The reaction vessel may be located downstream of a calcium removal vessel and receive a filtered bottom stream from that vessel, or it may be a single reaction vessel that cycles between a calcium removal mode and an acetate removal mode, with the pressure of the single vessel being greater during the calcium removal mode than during the acetate removal mode.
C07C 29/88 - SeparationPurificationStabilisationUse of additives by treatment giving rise to a chemical modification of at least one compound
B01D 3/00 - Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping
C07C 29/50 - Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by oxidation reactions with formation of hydroxy groups with molecular oxygen only
C07C 29/76 - SeparationPurificationStabilisationUse of additives by physical treatment
C07C 29/78 - SeparationPurificationStabilisationUse of additives by physical treatment by condensation or crystallisation
C10L 3/10 - Working-up natural gas or synthetic natural gas
43.
WELLHEAD GRIPPING ASSEMBLY INSTALLATION TECHNIQUE AND SETTING TOOL
A wellhead clamp for elastically deforming a wellhead housing to grip a wellhead hanger is provided. In one embodiment, a wellhead clamp (50) includes a first energizing ring (56), a second energizing ring (54), compression segments (52) positioned between the two energizing rings, and segment retainers (80) fastened to the compression segments and to the energizing rings. The segment retainers retain the compression segments between the energizing rings and hold the energizing rings apart in an expanded arrangement that allows the compression segments to be in a radially retracted position that facilitates running of the wellhead clamp onto the wellhead housing (20). A setting tool (110) can be used to apply a setting load to the wellhead clamp. The setting tool can be a hydraulic setting tool with pistons (132, 178), which may be bidirectional pistons in some instances, to apply the setting load. Additional systems, devices, and methods are also disclosed.
Methods and systems for managing hydrate formation in a hydrocarbon stream. The methods and systems include injecting into the hydrocarbon stream a thermodynamic hydrate inhibitor and a kinetic hydrate inhibitor. Addition of the kinetic hydrate inhibitor allows for reduction in the amount of thermodynamic hydrator inhibitor needed. The kinetic hydrate inhibitor has high temperature stability to allow for recycling and reuse.
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 43/013 - Connecting a production flow line to an underwater well head
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
45.
SYSTEMS AND METHODS FOR INSPECTIONS USING UNMANNED AUTONOMOUS VEHICLES
The disclosed techniques are directed to using unmanned autonomous vehicles to perform inspections of, for example, gas sensors or other assets located within a processing facility. For example, the unmanned autonomous vehicles may autonomously navigate through a processing facility to perform the inspections. In addition, one or more properties of data captured by the unmanned autonomous vehicles may be controlled based on real-time conditions to optimize the inspection of the assets of the processing facility. Furthermore, the unmanned autonomous vehicles may be configured to perform calibration of the assets when anomalies readings are collected. In addition, the unmanned autonomous vehicles may be self-learning autonomous devices configured to learning from data collected during previous inspections of assets.
Systems and methods presented herein generally relate to recycling, or reducing flaring or venting, of vent gases from glycol based dehydration of natural gas. Some systems and methods use high pressure gas, high pressure glycol, or pump-assisted high pressure glycol to provide motive energy to draw reflux gas and/or skimmer gas through one or more venturis and back to the contact tower of the dehydration system. Some systems and methods provide for harvesting energy from the dehydration process.
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
C10L 3/10 - Working-up natural gas or synthetic natural gas
47.
METHODS OF PREDICTING PROPERTIES OF A CHEMICAL SYSTEM USING SURROGATE MODELS
Methods of predicting physicochemical properties of a chemical system using a family of surrogate or reduced order models, trained on first principle simulation results. The models are created using machine learning techniques. The chemical system can be a complex multicomponent and multiphase system such as produced water.
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
Scale inhibitor compositions and methods for treating a subterranean hydrocarbon producing formation and/or oilfield equipment are disclosed. The scale inhibitor composition comprises a scale inhibitor comprising at least one copolymer, a corrosion inhibitor comprising at least one acid, a neutralizing agent, and an optional solvent. The methods inhibit corrosion of metal surfaces by contacting at least one metal surface with at least one scale inhibitor composition and treat the subterranean formation by contacting a subterranean zone of the subterranean formation with the scale inhibitor composition such that corrosive effects of an acidizing composition on metal surfaces in contact therewith are reduced.
Fracturing systems with frac valves for controlling flow of fracturing fluid are provided. In one embodiment, a fracturing apparatus includes a frac valve having a housing with a bore to convey fracturing fluid, a seal disposed within the bore, and an actuator coupled to control movement of the seal. The actuator can be disposed within the bore so as to move the seal between a closed position in which the seal blocks fracturing fluid flow through the bore and an open position that allows fracturing fluid flow through the bore. Additional systems, devices, and methods for fracturing are also disclosed.
A seal monitoring system includes at least one sensor configured to couple to an outer surface of a housing and to output a sensor signal indicative of deformation of the housing. The housing is configured to receive an insert within an internal cavity of the housing, and an engageable seal is configured to selectively establish a seal between the insert and the housing. The seal monitoring system also includes a controller communicatively coupled to the at least one sensor. The controller includes a memory and a processor, the controller is configured to determine a degree of engagement of the engageable seal based on the deformation of the housing. Additionally or alternatively, the controller is configured to determine a fluid pressure within the housing based on the deformation of the housing.
G01M 3/28 - Investigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables, or tubesInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipe joints or sealsInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for valves
G01L 9/04 - Measuring steady or quasi-steady pressure of a fluid or a fluent solid material by electric or magnetic pressure-sensitive elementsTransmitting 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 by making use of variations in ohmic resistance, e.g. of potentiometers of resistance strain gauges
51.
SYSTEM AND METHOD FOR VALVE GREASING IN A WELL TREE
A technique facilitates greasing of valves on a well tree, e.g. a frac tree, according to a simple process which enables selected, individual valves to be greased when desired. In some applications, the greasing process may be automated and controlled via a greasing control system. According to an embodiment, a greasing system is connected with grease ports at a plurality of actuatable valves located in a well tree. The greasing system has a plurality of grease valves which may be associated with each of the actuatable valves, e.g. with each of the grease ports. A pump is used to pump grease to the grease valves and the grease valves are selectively actuated to open positions to provide controlled greasing of desired actuatable valves so as to remove debris from and to lubricate selected actuatable valves.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 34/02 - Valve arrangements for boreholes or wells in well heads
F16N 11/00 - Arrangements for supplying grease from a stationary reservoir or the equivalent in or on the machine or member to be lubricatedGrease cups
F16N 13/22 - Lubricating-pumps with distributing equipment
52.
POWER UNIT PHASE ANGLE FOR SEPARATION UNIT CONTROL
Embodiments described herein provide a method of separating a liquid mixture, comprising providing a liquid mixture to a separator, electrically coupling a power circuit to the liquid mixture inside the separator, applying a time-varying voltage to the power circuit, detecting a phase angle in the power circuit; and controlling the phase angle by adjusting a characteristic of the time-varying voltage.
Smart wellhead assemblies with sensors for detecting positions of components within the bores of the wellhead assemblies are provided. In some instances, the sensors can be used to detect one or more of landing, locking, or concentricity of hangers, packoffs, or other internal wellhead components within bores. In one example, a method of installing a hanger within a wellhead includes lowering the hanger within the wellhead and using one or more sensors to detect when the hanger is at a target location. The method can also include activating a locking mechanism of the hanger and using the one or more sensors to detect when the locking mechanism has secured the hanger within the wellhead. Additional systems, devices, and methods are also disclosed.
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
A system includes a dispensing device having a material chamber to store an oilfield material and to fluidly couple to a wellhead, a plurality of flow control devices to control a flow of the oilfield material via the material chamber, a plurality of sensors to measure one or more properties related to the dispensing device, and a control system communicatively coupled to the dispensing device. The control system opens a first flow control device to fill the material chamber with the oilfield material, monitors a condition associated with the material chamber based on the properties measured via the plurality of sensors, opens a second flow control device to provide a high pressure fluid into the material chamber when the condition is present, and open a third flow control device, where the third flow control device fluidly couples the material chamber to the wellhead.
Embodiments of the present disclosure relate to a choke valve that includes a choke body, a choke trim disposed in the choke body, where the choke trim is configured to adjust a cross-sectional area of a flow path in the choke body to adjust a fluid flow through the choke valve, a needle of the choke trim disposed in the flow path of the fluid flow, where the needle includes a first portion having a superhard material, a seat of the choke trim, where the needle is configured to move along an axis extending through an opening of the seat to adjust the fluid flow through the choke valve.
F16K 1/48 - Attaching valve members to valve-spindles
F16K 1/52 - Means for additional adjustment of the rate of flow
F16K 25/00 - Details relating to contact between valve members and seats
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
A system including a valve. The valve includes a valve body having an interior volume and a bore along a first axis. A stem extends along a second axis and a flow control element couples to the stem. The stem selectively moves the flow control element through the interior volume between a closed position and an open position relative to the bore. A valve insert system retains a pressurized lubricant in the interior volume.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 3/20 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor with special arrangements for separating the sealing faces or for pressing them together by movement of the seats
F16K 31/50 - Mechanical actuating means with screw-spindle
A MEG recovery process is described, in which a MEG stream is processed by performing a divalent treatment to reduce dissolved divalent cations in the portion of the stream; performing a sulfate treatment to reduce dissolved sulfate ions in the stream, the sulfate treatment comprising adding an underdose of one or more calcium halides, one or more lower calcium carboxylates, or a mixture thereof to a treatment stream; and precipitating calcium sulfate from the treatment stream; performing a solids removal treatment to reduce solids in the stream; and returning the treated stream, depleted in divalent cations, sulfate ions, and solids, to the MEG recovery process.
Systems and methods presented herein generally relate to receiving real-time data from one or more sensors associated with equipment of a hydrocarbon well production system, predicting scale precipitation in the hydrocarbon well production system based at least in part on the real-time data, and automatically adjusting one or more operating parameters of the equipment based at least in part on the predicted scale precipitation. For example, automatically adjusting the one or more operating parameters of the equipment may include determining a scale inhibitor injection rate setpoint based at least in part on the predicted scale precipitation, and automatically adjusting a speed of one or more chemical injection pumps of a chemical injection system in accordance with the scale inhibitor injection rate setpoint.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
A technique facilitates utilization of a running tool system for use with a tubing hanger deployed at a wellhead. The running tool system may comprise a running tool which may be coupled to a hanger. The running tool may include a first sleeve which may be coupled to the hanger for moving the hanger in an axial direction. According to an embodiment, the running tool also may include a second sleeve which may be coupled to an adjustable landing ring disposed about the hanger. The second sleeve may be used to rotate the adjustable landing ring so as to lock the hanger in position.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
E21B 43/10 - Setting of casings, screens or liners in wells
60.
Corrosion inhibitor with improved performance at high temperatures
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C07D 239/04 - Heterocyclic compounds containing 1,3-diazine or hydrogenated 1,3-diazine rings not condensed with other rings having no double bonds between ring members or between ring members and non-ring members
A well treatment composition wax removal additives for the cleaning of a well containing hydrocarbons waxes. The wax removal additives comprise nano polysaccharides. A method of cleaning a hydrocarbon well containing at least one of wax, asphaltenes or scale, by injecting a nano polysaccharide solution.
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
A system for generating electrical power may include a flowline having an inlet that receives reservoir fluid at a first pressure, an outlet that outputs the reservoir fluid at a second pressure, a first flow path between the inlet and the outlet, and a second flow path between the inlet and the outlet, in parallel with the first flow path. The difference between the first pressure and the second pressure may include a pressure differential, and the system may include a valve that adjusts the pressure differential. Additionally, the system may include a turbine disposed along the second flow path that generates mechanical energy from a flow of the reservoir fluid induced by the pressure differential, and the mechanical energy may be converted to electrical energy.
A monitoring system includes one or more sensors coupled to a hanger running assembly that is configured to be inserted into a housing. The one or more sensors are configured to output sensor signals indicative of a respective distance between opposed ends of a lock ring of the hanger running assembly. The monitoring system also includes one or more processors configured to determine a condition of the lock ring based on the sensor signals.
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 33/043 - Casing headsSuspending casings or tubings in well heads specially adapted for underwater well heads
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
A monitoring system includes one or more sensors coupled to a hanger running assembly that is configured to be inserted into a housing. The one or more sensors are configured to output sensor signals indicative of a respective distance between opposed ends of a lock ring of the hanger running assembly. The monitoring system also includes one or more processors configured to determine a condition of the lock ring based on the sensor signals.
A monitoring system includes a first transducer component configured to couple to a running tool that is configured to place an insert into a housing and a second transducer component configured to couple to the housing. One of the first transducer component or the second transducer component is configured to emit acoustic waves, and the other one of the first transducer component or the second transducer component is configured to output sensor signals indicative of a received portion of the acoustic waves. The monitoring system also includes one or more processors configured to determine that the insert is in a landed position in the housing based on the sensor signals.
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
66.
Variable feed enclosed combustor system and method for its use
Disclosed herein are systems, apparatuses, and methods for using a sensed combustion zone temperature to continuously control combustion of a first (main) gas within an enclosed combustor. The combustor is in fluid communication with a first gas line carrying the first gas, a second gas line independent of the first gas line carrying a second (assist) gas having a higher heating value than the first gas, and air dampers providing draft or assist air. The first gas may be vapors from a production source or tank. A computer control system monitors the combustion zone temperature of the enclosed combustor as sensed by a sensor in electronic communication with the computer control system and controls the combustion zone temperature by changing a condition of a first gas line valve of the first gas line, a second gas line valve of the second gas line, and the air dampers.
F23G 7/08 - Methods or apparatus, e.g. incinerators, specially adapted for combustion of specific waste or low grade fuels, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases using flares, e.g. in stacks
F23G 7/06 - Methods or apparatus, e.g. incinerators, specially adapted for combustion of specific waste or low grade fuels, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases
A wellhead alignment system includes a visual marker configured to be placed at a wellhead and a camera configured to capture an image that includes the visual marker. The wellhead alignment system also includes one or more processors configured to apply computer vision algorithms to identify the visual marker in the image and to calculate an offset between the wellhead and a drilling rig based on a position of the visual marker in the image.
A wellhead alignment system includes a visual marker configured to be placed at a wellhead and a camera configured to capture an image that includes the visual marker. The wellhead alignment system also includes one or more processors configured to apply computer vision algorithms to identify the visual marker in the image and to calculate an offset between the wellhead and a drilling rig based on a position of the visual marker in the image.
A system includes a plug assembly having a housing configured to be positioned within a first passageway formed in a wellhead component. A channel is formed in the housing, and the channel is configured to enable fluid to flow from a bore of the wellhead component into the channel. A sensor is supported by the housing and is configured to measure a condition of the fluid within the channel. An annular seal is configured to extend between an outer surface of the housing and an inner surface of a second passageway formed in a flange that circumferentially surrounds at least part of the plug assembly while the flange is coupled to the wellhead component.
An actuator assembly includes a threaded shaft, a threaded nut that is threadably coupled to the threaded shaft, an annular ratchet positioned about the threaded shaft and comprising one or more tracks, and a pin that extends from the threaded shaft and into the one or more tracks. The threaded nut may include a first circumferentially-facing surface, the annular ratchet may include a second circumferentially-facing surface, and the first and second circumferentially-facing surfaces are configured to contact one another to enable the threaded nut to block rotation of the annular ratchet with the threaded shaft. The actuator assembly may enable the threaded nut to move to a limit position and hold full motor torque, but also to break free from the limit position with relatively low torque (e.g., less than the full motor torque; as compared to actuator systems that are devoid of certain features of the actuator assembly).
A diverter valve assembly includes a diverter valve. The diverter valve includes a housing having an inlet, multiple destination outlets, and a subsequent diverter valve outlet. The diverter valve also includes a rotary element disposed within the housing. The rotary element has an inlet, one or more target destination outlets, and a subsequent diverter valve outlet. Furthermore, the inlet of the rotary element is fluidly coupled to the inlet of the housing, the subsequent diverter valve outlet of the rotary element is fluidly coupled to the subsequent diverter valve outlet of the housing, and the rotary element is configured to rotate to selectively fluidly couple the one or more target destination outlets of the rotary element to one or more respective destination outlets of the housing.
F16K 11/085 - Multiple-way valves, e.g. mixing valvesPipe fittings incorporating such valvesArrangement of valves and flow lines specially adapted for mixing fluid with all movable sealing faces moving as one unit comprising only taps or cocks with cylindrical plug
F16K 27/06 - Construction of housingsUse of materials therefor of taps or cocks
A wellhead assembly with a gripping device for securing multiple components of the wellhead assembly is provided. In one embodiment, a system includes a wellhead housing mounted above a hollow body, such that an axial bore extends through the wellhead housing and the hollow body, and a wellhead hanger positioned within the axial bore. The system also includes a clamp that provides a first grip that secures the wellhead housing to the hollow body and a second grip that secures the wellhead hanger within the axial bore. The second grip includes elastic deformation, via the clamp, of at least one of the wellhead housing or the hollow body into tight engagement with an exterior of the wellhead hanger to secure the wellhead hanger at the location within the axial bore. Additional systems, devices, and methods are also disclosed.
A method for snubbing a wellhead hanger into a wellhead is provided. In one embodiment, a snubbing method includes snubbing a tubing hanger into a wellhead housing from a snubbing unit. Snubbing the tubing hanger into the wellhead housing can include lowering the tubing hanger into a bore of the wellhead housing under pressure and allowing fluid in the bore to pass along an exterior of the tubing hanger to balance fluid pressure above and below the tubing hanger as the tubing hanger is lowered. The tubing hanger can be positioned at a location in the bore of the wellhead housing, which can be elastically deformed to grip and secure the tubing hanger at the location in the bore. Additional methods, systems, and devices are also disclosed.
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
74.
Fracturing tree with valves and bore junction in shared body
A fracturing tree with valves and a junction of vertical and horizontal bores located within a shared, single block of metal is provided. In one embodiment, a system includes a hydraulic fracturing tree mounted over an onshore wellhead. The hydraulic fracturing tree includes a vertical bore and a horizontal bore that meet. A junction of the vertical bore with the horizontal bore is located in a single block of metal of the hydraulic fracturing tree. The hydraulic fracturing tree also includes a first valve positioned along the vertical bore and a second valve positioned along the horizontal bore. Both of the first and second valves can be located in the single block of metal having the junction of the vertical bore with the horizontal bore. Additional systems, devices, and methods are also disclosed.
Production chemicals and methods of selecting the production chemicals based on Hansen Solubility Parameters (HSP) are disclosed. The production chemicals selected by the methods mitigate or reduce one or more issues or problems associated with oil and gas productions and transportations. The methods measure HSP values for the production chemicals and/or crude oil and select at least one production chemical for at least one application on the crude oil based on the HSP values of the production chemicals and the crude oil.
A ball valve assembly includes a ball configured to rotate between an open position and a closed position. The ball valve assembly also includes an annular seat configured to engage the ball and a rotatable ring having a first engagement feature. In addition, the ball valve assembly includes a non-rotatable ring positioned adjacent to the rotatable ring. The ball valve assembly also includes a drive plate non-rotatably coupled to the ball. The drive plate includes a second engagement feature, and the second engagement feature is configured to engage the first engagement feature to drive the rotatable ring to rotate in response to rotation of the drive plate. Furthermore, the ball valve assembly includes a bearing element configured to drive the rotatable ring and the non-rotatable ring away from one another to compress the annular seat against the ball in response to rotation of the rotatable ring.
F16K 5/20 - Special arrangements for separating the sealing faces or for pressing them together for plugs with spherical surfaces
F16K 5/06 - Taps or cocks comprising only cut-off apparatus having at least one of the sealing faces shaped as a more or less complete surface of a solid of revolution, the opening and closing movement being predominantly rotary with plugs having spherical surfacesPackings therefor
F16K 27/06 - Construction of housingsUse of materials therefor of taps or cocks
77.
PRODUCTION CHEMICALS AND METHODS OF SELECTING THE PRODUCTION CHEMICALS BASED ON HANSEN SOLUBILITY PARAMETERS
Production chemicals and methods of selecting the production chemicals based on Hansen Solubility Parameters (HSP) are disclosed. The production chemicals selected by the methods mitigate or reduce one or more issues or problems associated with oil and gas productions and transportations. The methods measure HSP values for the production chemicals and/or crude oil and select at least one production chemical for at least one application on the crude oil based on the HSP values of the production chemicals and the crude oil.
A fracturing fluid delivery system is provided. In one embodiment, the system includes a fracturing manifold and a fracturing tree. A fluid conduit is coupled between the fracturing manifold and the fracturing tree to enable receipt of fracturing fluid by the fracturing tree from the fracturing manifold through the fluid conduit. The fluid conduit includes a flexible pipe segment between rigid ends of the fluid conduit. Additional systems, devices, and methods are also disclosed.
A method includes receiving an indication of an emission plume traveling along a first direction. The method also includes determining a cross-section of the emission plume, wherein the cross-section is substantially perpendicular to the first direction. Further, the method includes determining a travel path for an optical detector to obtain optical measurements along the cross-section, wherein the travel path extends in a second direction along the cross-section, and the optical detector is configured to obtain the optical measurements in a third direction crosswise to the travel path.
An annulus pressure release system includes a gas metering valve assembly having a fluid pathway. The gas metering valve assembly includes a pressure sensor configured to be fluidly coupled to an annulus and to output a sensor signal indicative of a fluid pressure within the annulus. The gas metering valve assembly also includes an electronically actuated adjustable control valve disposed along the fluid pathway and a electronically actuated two-position valve disposed along the fluid pathway. Furthermore, the gas metering valve assembly includes a flow controller. The flow controller, in response to determining the fluid pressure exceeds a threshold pressure, is configured to output a first control signal to the electronically actuated two-position valve indicative of instructions to open the electronically actuated two-position valve, and to output a second control signal to the electronically actuated adjustable control valve indicative of instructions to adjust a flow of fluid through the fluid pathway.
A frac system including a frac tree. The frac tree includes a frac head. The frac head defines a first inlet, a second inlet, and an outlet. The frac head receives frac fluid through the first inlet and directs the frac fluid to the outlet fluidly coupled to a wellhead. A valve couples to the second inlet of the frac head. A flapper valve is within the frac head. The flapper valve moves between an open position and a closed position to control fluid flow to the valve through the second inlet. The flapper valve aligns with a first axis of the outlet and the second inlet in the closed position and aligns with a second axis of the first inlet in the open position.
A wellhead system includes a wellhead including a position sensor disposed in an inner surface of the wellhead, and a wellhead component to be installed in the wellhead, the wellhead component including a position indicator disposed in an outer surface of the wellhead component, wherein the position sensor is configured to transmit a position signal in response to the wellhead component entering into a predetermined aligned position in the wellhead.
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
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
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
Systems and methods presented herein generally relate to greenhouse gas emission management and, more particularly, to a greenhouse gas emission management workflow to perform greenhouse gas detection sensor placement or greenhouse gas leak detection. For example, the system and method enable improved gas sensor arrangements within an oil and gas worksite. In another example, the system and method enable the prediction of a location and a leak rate of a gas leak within an oil and gas production facility based on measurements collected by gas leak sensors disposed within the facility and prevailing wind information.
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
G01W 1/02 - Instruments for indicating weather conditions by measuring two or more variables, e.g. humidity, pressure, temperature, cloud cover or wind speed
G06F 30/20 - Design optimisation, verification or simulation
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
84.
Coupling agents for use in corrosion inhibiting compositions
Corrosion inhibition compositions and methods useful for inhibiting corrosion are provided. The corrosion inhibition compositions comprise at least one coupling agent and at least one corrosion inhibitor, wherein the at least one coupling agent is at least one of one or more ether amines, one or more ether amine oxides, and at least one combination thereof, and the at least one corrosion inhibitor is at least one selected from one or more thiophosphates, one or more polyphosphate esters, one or more imidazolines, one or more quinolines, one or more alkynols, one or more alkynol derivatives, and at least one combination thereof. The methods for inhibiting corrosion on metal surfaces utilize the disclosed corrosion inhibiting compositions.
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
Corrosion inhibition compositions and methods useful for inhibiting corrosion are provided. The corrosion inhibition compositions comprise at least one filming agent and at least one promoting agent and the methods for inhibiting corrosion on metal surfaces utilize the disclosed corrosion inhibiting compositions.
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
Embodiments of the present disclosure relate to a choke valve that includes a choke body, a choke trim disposed in the choke body, where the choke trim is configured to adjust a cross-sectional area of a flow path in the choke body to adjust a fluid flow through the choke valve, a needle of the choke trim disposed in the flow path of the fluid flow, where the needle includes a first portion having a superhard material, a seat of the choke trim, where the needle is configured to move along an axis extending through an opening of the seat to adjust the fluid flow through the choke valve.
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
F16K 1/48 - Attaching valve members to valve-spindles
Embodiments described herein provide a method, comprising routing a bio-oil to a mixing device; routing a wash material to the mixing device; using the mixing device to form a mixture from the bio-oil and the wash material; routing the mixture to an electrostatic separator; and applying an electric field to the mixture, in the electrostatic separator, to separate the wash material from the bio-oil.
C10G 53/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
Fracturing fluid delivery systems having components with sacrificial liners or sleeves are provided. In one example, a fracturing system includes a flexible fracturing fluid conduit coupled to a wellhead assembly. The flexible fracturing fluid conduit includes a flexible body, a rigid end joined to the flexible body, and a bore extending through the flexible body and the rigid end for conveying fracturing fluid to the wellhead assembly. The flexible fracturing fluid conduit also includes a rigid sacrificial sleeve installed in the rigid end and within the bore. In another example, a fracturing system includes a fracturing fluid delivery apparatus coupled to a wellhead. The fracturing fluid delivery apparatus includes a pressure-containing component having a rigid body with a bore for conveying fracturing fluid. The pressure-containing component has a sacrificial liner provided through the bore along an interior surface of the rigid body. Additional systems, devices, and methods are disclosed.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
F16L 11/12 - Hoses, i.e. flexible pipes made of rubber or flexible plastics with arrangements for particular purposes, e.g. specially profiled, with protecting layer, heated, electrically conducting
F16L 57/06 - Protection of pipes or objects of similar shape against external or internal damage or wear against wear
E21B 34/02 - Valve arrangements for boreholes or wells in well heads
89.
SYSTEMS AND METHODS FOR GREENHOUSE GAS EMISSION QUANTIFICATION AND REDUCTION
Systems and methods presented herein generally relate to a method that includes providing one or more recommendations relating to greenhouse gas emission reduction goals to a customer. The method also includes receiving one or more greenhouse gas emission reduction goals from the customer. The one or more greenhouse gas emission reduction goals relate to a reduction in greenhouse gas emissions at one or more oil and gas worksites associated with the customer. The method also includes determining a greenhouse gas emission reduction plan to reduce the greenhouse gas emissions at the one or more oil and gas worksites to achieve the one or more greenhouse gas emission reduction goals. The method further includes performing work to implement the greenhouse gas emission reduction plan. The method also includes collecting and analyzing greenhouse gas emission measurements to ensure that the one or more greenhouse gas emission reduction goals have been achieved by the greenhouse gas emission reduction plan.
Citrate polyester additives for crude oils, mixtures of the citrate polyester additives and crude oils, and methods for producing or forming the mixtures are provided. The mixtures and methods comprise at least one citrate polyester additive introduce or applied to crude oil, wherein the at least one citrate polyester additive comprises one or more citrate crosspolymers.
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
C08L 67/04 - Polyesters derived from hydroxy carboxylic acids, e.g. lactones
C08L 101/00 - Compositions of unspecified macromolecular compounds
C08G 63/06 - Polyesters derived from hydroxy carboxylic acids or from polycarboxylic acids and polyhydroxy compounds derived from hydroxy carboxylic acids
C08G 63/91 - Polymers modified by chemical after-treatment
A choke gate valve includes a housing that defines a fluid bore and a gate that includes a throttling orifice. The gate is configured to move within the housing between a throttle position in which the gate extends across the fluid bore to position the throttling orifice in the fluid bore to throttle a fluid flow through the fluid bore and an open position in which the gate does not block the fluid bore to enable a full level of the fluid flow through the fluid bore. The choke gate valve may be used as part of a choke gate valve system to transition between first fracturing operations for a first well and second fracturing operations for a second well without shut off of a pump.
A seat assembly for a choke valve assembly includes a housing having an internal passage, in which the housing is formed from a non-superhard material. The seat assembly also includes a seat disposed within the internal passage of the housing. The seat is configured to engage a needle of the choke valve assembly while the choke valve assembly is in a closed state, and the seat is formed from a first superhard material. In addition, the seat assembly includes an annular insert disposed within the internal passage of the housing downstream from the seat. The annular insert is formed from a second superhard material, and a maximum cross-sectional area of the seat along a longitudinal axis of the seat assembly is greater than a maximum cross-sectional area of the annular insert along the longitudinal axis.
A power supply device includes a power conversion circuit configured to convert an input voltage into an output voltage, a controller, and an output switch. The controller is coupled to the power conversion circuit and configured to control the power conversion circuit to generate the output voltage for causing electrical coalescence of a multi-phase liquid mixture when the output voltage is applied to the multi-phase liquid mixture. The output switch is coupled between an output of the power conversion circuit and a terminal of the power supply device. The output switch is switchable among a first position at which the output of the power conversion circuit is coupled to the terminal, a second position at which the output of the power conversion circuit is grounded, and a third position at which the output of the power conversion circuit is electrically isolated from the terminal and the ground.
H02M 3/335 - Conversion of DC power input into DC power output with intermediate conversion into AC by static converters using discharge tubes with control electrode or semiconductor devices with control electrode to produce the intermediate AC using devices of a triode or a transistor type requiring continuous application of a control signal using semiconductor devices only
B01D 17/06 - Separation of liquids from each other by electricity
B03C 11/00 - Separation by high-voltage electrical fields, not provided for in other groups of this subclass
C10G 33/02 - De-watering or demulsification of hydrocarbon oils with electrical or magnetic means
94.
Citrate polyester additives for crude oil, mixtures of said additives and crude oil, and methods for producing said mixtures
Citrate polyester additives for crude oils, mixtures of the citrate polyester additives and crude oils, and methods for producing or forming the mixtures are provided. The mixtures and methods comprise at least one citrate polyester additive introduce or applied to crude oil, wherein the at least one citrate polyester additive comprises one or more citrate crosspolymers.
C08G 63/06 - Polyesters derived from hydroxy carboxylic acids or from polycarboxylic acids and polyhydroxy compounds derived from hydroxy carboxylic acids
A method is described herein, comprising vaporizing a glycol material by thermal contact with a heating medium to form a vaporized glycol stream, increasing a pressure of the vaporized glycol stream to form a pressurized glycol stream, and increasing a temperature of the heating medium by thermally contacting the heating medium with the pressurized glycol stream.
A system including a valve. The valve includes a valve body having an interior volume and a bore along a first axis. A stem extends along a second axis and a flow control element couples to the stem. The stem selectively moves the flow control element through the interior volume between a closed position and an open position relative to the bore. A valve insert system retains a pressurized lubricant in the interior volume.
F16K 3/20 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor with special arrangements for separating the sealing faces or for pressing them together by movement of the seats
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 31/50 - Mechanical actuating means with screw-spindle
Embodiments described herein provide a method of tuning an electrical liquid separator, comprising providing a liquid mixture to a separator; electrically coupling a power unit to the liquid mixture inside the separator; applying a time-varying voltage from the power unit to the liquid mixture; increasing a voltage applied to the liquid mixture from the power unit from a first voltage to a second voltage; detecting an inflection point in a current from the power unit; setting a voltage output range of the power unit to encompass a voltage at which the inflection point was detected.
Techniques for positioning and setting a barrier within a well string are provided. In one embodiment, a method includes securing a barrier device at a lubricator extension of a lubricator assembly and positioning the lubricator assembly at a wellhead assembly having a wellhead from which a well string is suspended. The method also includes advancing the lubricator extension to advance the barrier device into the well string. The barrier device may be set within the well string to block flow. Additional methods, systems, and devices are also disclosed.
A membrane assembly includes a tube container having an inlet conduit and a first outlet conduit both oriented in a radial direction, and a second outlet conduit oriented in an axial direction; and a hollow fiber membrane element disposed inside the tube container, the hollow first membrane element comprising a first adapter with an axial permeate fluid passage in a center thereof and an inlet gas passage in a peripheral portion thereof; and a second adapter with an axial permeate fluid passage in a center thereof and a non-permeate fluid passage in a peripheral portion thereof.
B01D 53/22 - 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 diffusion
A surface well fracturing system having fluid conduits connected to surface fracturing equipment with quick connect systems is provided. In one embodiment, a fracturing system includes a frac pump, a frac supply manifold, and a fracturing fluid conduit connected to route fracturing fluid between the frac pump and the frac supply manifold. The fracturing fluid conduit is connected to the frac pump or to the frac supply manifold by a quick connect apparatus, which includes a segmented clamp having multiple clamp segments mounted on a shared support. Additional systems, devices, and methods are also disclosed.
