A method including processing an extract stream in one or more KHI processing units to generate a purified product and a process waste, wherein the extract stream includes an extraction solvent and a kinetic hydrate inhibitor (KHI), and the purified product has a higher concentration of the KHI than the extract stream, and processing the purified product in a KHI reformulation unit to generate a reformulated KHI based on a KHI formulation.
A method includes receiving a source stream into a liquid-liquid extractor. The source stream includes a rich mono ethylene glycol (MEG) and a kinetic hydrate inhibitor (KHI) actives. The method also includes receiving an extraction solvent into the liquid-liquid extractor, wherein the extraction solvent has an affinity for the KHI actives. The method also includes separating the source stream into an extract stream and a raffinate stream in the liquid-liquid extractor via a liquid-liquid extraction using the extraction solvent, outputting the extract stream including the KHI actives and the extraction solvent, and outputting the raffinate stream including the rich MEG.
A system for improved water separation from oil and gas production is described. In one aspect, a system for improved water separation from oil and gas production is provided. The system includes a system for water separation from oil and gas production, comprising an inlet section configured to receive a production stream line, the inlet section comprising a gas disengagement system comprising a flow control vessel and a gas disengagement line coupled to the flow control vessel, a stratification section downstream of the inlet section, the stratification section comprising a mixing device coupled to the gas disengagement system and a stratification line disposed downstream of the mixing device, wherein the stratification line comprises at least one 180° turn, and a separator section, comprising a separator coupled to the stratification line and one or more recycle lines fluidly coupled to the separator.
An inhibitor composition includes a hyperbranched polymer in an amount of 1 to 50 weight percentage of total weight of the inhibitor composition. The hyperbranched polymer comprises a main anchoring group with functionalized pendant chains with at least two polar functional groups. The inhibitor composition also includes at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.
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
Corrosion inhibitors, corrosion inhibitor compositions, methods of making the same, and methods of using the same include a corrosion inhibitor composition having an amino acid functionalized phytic acid in a solvent composed to retain the corrosion inhibitor therein. The corrosion inhibitor composition is added to a wellbore fluid to limit corrosion on drilling and production equipment.
A process for monoethylene glycol (MEG) recovery including feeding a MEG rich stream having water, dissolved monovalent salts, and MEG into a flash separator, where the flash separator is configured to at least partially separate the monovalent salts from the MEG in the MEG rich stream. The process also includes obtaining an overhead stream from the flash separator, where the overhead stream has a first portion of the MEG rich stream, obtaining a bottoms stream from the flash separator, where the bottoms stream has a second portion of the MEG rich stream; and feeding the overhead stream into a distillation column configured to at least partially separate water from MEG within the overhead stream. The process further includes obtaining a processed MEG stream from the distillation column, and directing the processed MEG stream to a polyethylene terephthalate (PET) polymerization system to generate PET polymers and plastic.
C07C 29/09 - Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by hydrolysis
C08J 11/24 - Recovery or working-up of waste materials of polymers by chemically breaking down the molecular chains of polymers or breaking of crosslinks, e.g. devulcanisation by treatment with organic material by treatment with organic oxygen-containing compounds containing hydroxyl groups
A hanger running assembly for a wellhead includes a hanger to support a casing. The hanger running assembly also includes a seal assembly with a push ring and a seal body to support one or more seal elements. The hanger running assembly further includes a torque tool coupled to the push ring via one or more shear pins, wherein rotation of the torque tool in a first direction while the one or more shear pins are intact causes rotation of the push ring in the first direction to thread onto the hanger.
A split housing connector assembly for a wellhead housing includes a housing portion, a connector portion, and multiple fasteners configured to couple the housing portion and the connector portion to one another. The connector portion includes at least one tapered portion to enable the multiple fasteners to be within an outer diameter of the connector portion while the multiple fasteners couple the housing portion and the connector portion to one another.
A system including a casing hanger; a wellhead housing, including a landing shoulder configured to contact the casing hanger during installation of the casing hanger in a wellhead; a transducer disposed on an exterior of the wellhead housing, wherein the transducer is configured to emit an input pulse toward the landing shoulder; and an ultrasonic transmitter coupled to the transducer, wherein the ultrasonic transmitter is configured to detect the input pulse and one or more echo pulses associated with the input pulse.
Methods and compositions for dissolving metal containing scale are described herein. An aqueous dissolver solution is applied to a metal surface having metal containing scale and the contact is maintained for a duration selected to reduce or remove the scale.
A non-transitory computer readable medium stores instructions that, when executed by a processor, cause the processor to receive, via a user interface of a mobile device, instructions to begin an inspection of a surface of a part, capture, via a camera of the mobile device, a video of the surface of the part as the mobile device is moved about the part, receive, via the user interface of the mobile device, information associated with the part, the inspection, or both, generate, via the processor of the mobile device, an inspection data set comprising the video and the information, and display, via the user interface of the mobile device, an indication of whether the surface of the part passed the inspection or failed the inspection based on a machine learning-based analysis of the inspection data set.
A wellhead includes a wellhead housing and a hanger configured to support a casing within the wellhead housing. The wellhead housing, the hanger, or both includes one or more passageways. A seal element is configured to transition from a solid state in a first configuration to a flowable state to flow into the one or more passageways and to transition from the flowable state to the solid state in a second figuration to seal the one or more passageways.
A wellhead includes a wellhead housing, a passage formed in or along the wellhead housing, a hanger configured to support a casing within the wellhead housing, and a seal assembly coupled to or integrally formed with the hanger. The seal assembly includes one or more seal elements with a wavy shape along a circumferential axis.
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
Provided herein is a method for generating a glycerol-based scale inhibitor and utilizing it to generate a glycerol-based scale inhibitor solution. The method includes providing a glycerol feed and a scale-inhibiting precursor to generate the glycerol-based scale inhibitor. Further, the method includes providing one or more additives to the one or more glycerol-based scale inhibitor, thereby generating a glycerol-based scale inhibitor solution.
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
16.
SYSTEMS AND METHODS FOR ELECTRICAL POWER GENERATION
A generator unit of a system for generating electrical power includes a generator coupled to a turbine. A flowline coupled to the generator unit conveys a fluid to an inlet of the turbine. A second flowline couples an outlet of the turbine and a tree of a well at a wellsite. The second flowline conveys the fluid from the outlet to the tree.
A system for inspecting one or more gas plumes in a facility, including a processor and a memory having instructions executable by the processor, wherein the instructions are configured to obtain one or more images from one or more cameras, wherein the one or more images include a gas plume. The instructions are further configured to focus the one or more images on an area of interest with an object detection model to generate a boundary box around the gas plume, and focus the one or more images on the area of interest with a segmentation model to generate a mask around the gas plume based on the boundary box. The instructions are further configured to obtain one or more masked images from the segmentation model, and analyze the one or more masked images to obtain an image analysis of one or more parameters of the gas plume.
This disclosure generally relates to systems and methods for inspecting one or more equipment of a facility. The system may be configured to obtain one or more images including an equipment from one or more cameras, wherein the one or more cameras are fixed within the facility or are attached to an unmanned autonomous vehicle; focus the one or more images on an area of interest with an object detection model to generate a boundary box around the equipment; focus the one or more images on the area of interest with a segmentation model to generate a mask around the equipment based on the boundary box; obtain one or more masked images from the segmentation model; and analyze the one or more masked images to obtain an image analysis of one or more parameters of the equipment.
Aspects of the disclosure provide for power generation from produced water. A method includes extracting production fluid from an oil well, wherein the production fluid includes water, wherein the water is at a first input temperature. The method includes diverting at least the water of the production fluid to an on-site power generation system. The method includes converting heat energy of the water to electrical energy at the on-site power generation system, wherein after the converting the water is a second output temperature lower than the first input temperature.
F03G 4/00 - Devices for producing mechanical power from geothermal energy
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
E21B 41/00 - Equipment or details not covered by groups
20.
SYSTEMS AND METHODS FOR DOWNHOLE SOLID SCALE INHIBITORS
The present disclosure is directed to systems and methods for delivering a solid scale inhibitor to produced fluids within a wellbore. The system may include a container containing a solid scale inhibitor and a flow diverter connected to the container. The flow diverter may include an adjustable aperture configured to control a flow of produced fluids into the container. Enlarging the aperture may increase a flow into the container and result in a greater dissolution of solid scale inhibitor, whereas reducing the size of the aperture may reduce a flow into the container and result in a lesser dissolution of solid scale inhibitor. One or more sensors may monitor one or more downhole conditions within the wellbore, and a control system may be configured to autonomously or semi-autonomously adjust the flow diverter based on information received from the sensors.
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 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
22.
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.
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
23.
SYSTEMS AND METHODS FOR CEMENTING CASING AND SEALING A HANGER IN A WELLHEAD HOUSING
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
24.
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.
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
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 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
32.
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
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
37.
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
38.
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 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
41.
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
43.
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
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 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.
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 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.
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"
51.
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 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.
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.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/06 - Valve arrangements for boreholes or wells in wells
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 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 33/064 - Blow-out preventers specially adapted for underwater well heads
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
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
G01B 21/32 - Measuring arrangements or details thereof, where the measuring technique is not covered by the other groups of this subclass, unspecified or not relevant for measuring the deformation in a solid
G01L 19/08 - Means for indicating or recording, e.g. for remote indication
57.
REMOVAL OF SULFATE FROM MEG STREAMS USING CALCIUM CHLORIDE
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.
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.
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 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A 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 11/07 - 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 sliding valves with linearly sliding closure members with cylindrical slides
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 27/04 - Construction of housingsUse of materials therefor of sliding valves
61.
GREENHOUSE GAS EMISSION MONITORING SYSTEMS AND METHODS
Systems and methods presented herein generally relate to greenhouse gas emission monitoring and, more particularly, to a greenhouse gas emission monitoring workflow using various different types of sensors. For example, a system includes a plurality of se nsors located within an oil and gas worksite. At least one sensor of the plurality of sensors is configured to detect a status of equipment at the oil and gas worksite. The system also includes a greenhouse gas emission analysis system configured to receive sensor data from the plurality of sensors. The greenhouse gas emission analysis system is also configured to correlate the sensor data from the plurality of sensors (e.g., using one or more reduced order models (ROMs) that reduce the computational complexity of computational fluid dynamics model simulations of previously collected data relating to operation of the oil and gas worksite )). The greenhouse gas emission analysis system is further configured to determine an existe nce of a greenhouse gas emission within the oil and gas worksite, a location of the greenhouse gas emission within the oil and gas worksite, and a quantity of the greenhouse gas emission within the oil and gas worksite based at least in part on the correlation.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
G01D 21/02 - Measuring two or more variables by means not covered by a single other subclass
62.
SYSTEMS AND METHODS FOR PROCESSING PRODUCED OILFIELD BRINE
Systems and methods presented herein relate to processing produced oilfield brine by deconstructing it into two useful components: (1) desalinated water and (2) a suspension of solid state salt (e.g., crystallized salt) slurried in a salt saturated brine, which may be formulated and injected into hydrocarbon producing for mations above hydraulic fracturing pressure to intentionally create regions of localized high stress within the respective formations. In addition, systems and methods presented herein relate to processing oilfield brine received from hydrocarbon producin g wells by : (1) coupling high pressure desalination technologies with saltwater disposal (SWD) operations, (2) active management of SWD water composition at the rock face through dual stream (e.g., split stream) injection, and /or (3) coupled SWD injection, flow assurance, and stimulation to minimize SWD formation d amage and injection pressures.
Systems and methods presented herein generally relate to a method that includes using a low-shear addition system at a centralized facility to add a friction-reducing additive to a fluid to produce friction-reduced hydraulic fracturing slurry. The method also includes conveying the friction-reduced hydraulic fracturing slurry from the centralized facility to at least one fracturing site. The method further includes injecting the friction-reduced hydraulic fracturing slurry into a reservoir to stimulate at least one well at the at least one fracturing site.
Systems and methods presented herein generally relate to a method that includes receiving water at a centralized facility. The method also includes receiving sand from one or more sand mines at the centralized facility. The method further includes receiving one or more chemicals at the centralized facility. In addition, the method includes using processing equipment of the centralized facility to process the water, the sand, and the one or more chemicals to produce a fracturing slurry. The method also includes conveying the fracturing slurry from the centralized facility to one or more fracturing sites.
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.
G01F 15/00 - Details of, or accessories for, apparatus of groups insofar as such details or appliances are not adapted to particular types of such apparatus
G01F 15/18 - Supports or connecting means for meters
G01F 1/66 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
A fracturing fluid delivery system having a fracturing line with a flexible liner is provided. In one embodiment, a method includes moving a flexible polymeric liner through a bore of a fracturing line to a position in which the flexible polymeric liner extends along an inner wall of a flexible pipe body of the fracturing line. The method also includes securing the flexible polymeric liner in the bore of the fracturing line, such as by attaching the flexible polymeric liner to an opposing surface of the fracturing line. Additional systems, devices, and methods are also disclosed.
Fracturing systems with frac valves having gates for controlling flow of fracturing fluid are provided. In one embodiment, a fracturing apparatus includes a frac valve having a housing with a cavity transverse to a bore. A gate is positioned in the cavity and is movable between open and closed positions to selectively block flow through the bore. The gate includes a seal assembly positioned to seal against a sidewall of the cavity to surround the bore and block flow through the frac valve when the gate is in the closed position. The seal assembly can be actuated between a less-energized state and a more-energized state following movement of the gate within the cavity from the open position to the closed position. Additional systems, devices, and methods for fracturing are also disclosed.
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 5/06 - 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
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.
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.
Fracturing fluid delivery systems having flexible fracturing fluid delivery conduits secured with quick connectors are provided. In one example, a fracturing system includes a wellhead assembly and a fracturing fluid conduit coupled to the wellhead assembly to route fracturing fluid to the wellhead assembly. The fracturing fluid conduit includes a flexible body defining a bore for conveying the fracturing fluid to the wellhead assembly. The fracturing fluid conduit is coupled to the wellhead assembly via an actuated connector including one or more locking members that move from an unlocked position to a locked position to secure the fracturing fluid conduit to the wellhead assembly. Additional systems, devices, and methods are also disclosed.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/013 - Connecting a production flow line to an underwater well head
E21B 17/043 - CouplingsJoints between rod and bit, or between rod and rod threaded with locking means
E21B 17/046 - CouplingsJoints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
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.
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.
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
E21B 33/076 - Well headsSetting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
E21B 33/126 - PackersPlugs with fluid-pressure-operated elastic cup or skirt
A rotating choke assembly includes a rotating control device and a flow control device. The rotating control device has a seal element configured to be disposed around a tubular, where the seal is configured to rotate in a circumferential direction via rotation of the drill string and a bearing configured to facilitate rotation of the seal element in the circumferential direction within a housing of the rotating control device. The flow control device includes a first plate having at least one first opening and a second plate having at least one second opening, where the first plate is configured to rotate in the circumferential direction with respect to the second plate.
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.
A system an annular sleeve configured to be positioned in an annular space between a first annular component and a second annular component of a drilling system. The annular sleeve includes a radially-inner annular surface and a radially-outer annular surface. The annular sleeve also includes a first annular seal element coupled to the radially-inner annular surface and configured to seal against the first annular component, a second annular seal element coupled to the radially-outer annular surface and configured to seal against the second annular component, and one or more axially-extending passageways extending from a first end to a second end of the annular sleeve. The annular sleeve is configured to direct a fluid flow through the one or more axially-extending passageways across the annular sleeve.
A sealing assembly is configured to form a seal to separate a higher-pressure environment from a lower-pressure environment. The sealing assembly includes a first elastomeric member comprising a first tapered contacting surface and a second elastomeric member comprising a second tapered contacting surface. The first elastomeric member and the second elastomeric member are configured to form the seal as at least a first portion of the first tapered contacting surface and at least a second portion of the second tapered contacting surface are forced into contact with one another.
A tubular handling system includes a tubular engaging device configured to engage and lift a tubular, an extensible piston having an upper end and a lower end, a first sheave at the upper end, a second sheave at the lower end, and a line extending around and between the first and second sheaves and connected to the tubular engaging device, such that extending the extensible piston raises the tubular engaging device and retracting the extensible piston lowers the tubular engaging device.
A device includes a loader configured to receive a tubular member in a substantially horizontal position and to pivot the tubular member into a substantially vertical position. The device also includes a barrel coupled to the loader and configured to receive the tubular member from the loader when the tubular member is in the substantially vertical position and to move the tubular member through a path at least partially around a central longitudinal axis through the barrel.
A mast for a drilling rig includes a front leg and a back leg. The front leg extends at a first angle with respect to horizontal such that a lower end of the front leg is configured to be farther away from a well center plane than an upper end of the front leg. The back leg extends at a second angle with respect to horizontal such that a lower end of the back leg is configured to be farther away from the well center plane than an upper end of the back leg. The first angle is different than the second angle. The lower end and the upper end of the front leg and the lower end and the upper end of the back leg are configured to be on a same side of the well center plane.
A mud shearing unit including an inlet, an outlet, a diffusion chamber connected to the outlet, a shearing nozzle connected between the inlet and the diffusion chamber, and a static fan interrupting mud flowing from the shearing nozzle to the outlet. A mud shearing system includes the mud shearing unit, a high-pressure (HP) mud pump, and a tank. The HP mud pump pumps mud to the mud shearing unit inlet at a first pressure. The tank is connected to the mud shearing unit outlet, thereby receiving mud from the mud shearing unit at a second pressure that is less than the first pressure. The mud shearing unit may provide a predetermined pressure drop range between the first and second pressures. The tank may be multiple tanks, and the system may further include a low-pressure manifold connected between the mud shearing unit outlet and each tank.
A technique facilitates monitoring fluid phases of a multiphase flow during, for example, well fluid production operations. According to an embodiment, data may be obtained from devices, such as chokes and pressure sensors. This data is then processed to identify phases of the multiphase well fluid flow. The use of data from such well related devices effectively establishes a virtual multiphase flowmeter. However, the output from the virtual multiphase flowmeter may be calibrated periodically by taking measurements from an actual multiphase flowmeter. In some embodiments, the data from a plurality of flow meters having differing physical operating principles may be correlated in a manner to obtain additional parameters related to the multiphase well fluid flow.
G01F 1/20 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects by detection of dynamic effects of the flow
G01F 15/00 - Details of, or accessories for, apparatus of groups insofar as such details or appliances are not adapted to particular types of such apparatus
G01F 15/02 - Compensating or correcting for variations in pressure, density, or temperature
G01F 15/075 - Integration to give total flow, e.g. using mechanically-operated integrating mechanism using electrically-operated integrating means
A choke valve includes a choke body and a choke trim disposed within the choke body. The choke trim also includes an insert defining a plurality of positive beans and a plate defining an aperture. The plate is configured to contact and to rotate relative to the insert to cover and uncover the plurality of positive beans to adjust a fluid flow through the choke valve.
A virtual integration test system includes a computer configured to receive data indicative of measured dimensions of as-built components. The computer is also configured to perform a motion mechanics simulation on at least two deformation-uncritical components of the as-built components and perform a deformation mechanics simulation on at least one deformation-critical component of the as-built components. The motion mechanics simulation and the deformation mechanics simulation are performed concurrently within a simulation environment. In addition, the computer is configured to determine interface and integration compatibility of the as-built components based on the motion mechanics simulation and the deformation mechanics simulation, and to output an output signal indicative of the interface and integration compatibility of the as-built components.
G06F 30/20 - Design optimisation, verification or simulation
G06F 30/17 - Mechanical parametric or variational design
G01B 21/02 - Measuring arrangements or details thereof, where the measuring technique is not covered by the other groups of this subclass, unspecified or not relevant for measuring length, width, or thickness
G01B 21/20 - Measuring arrangements or details thereof, where the measuring technique is not covered by the other groups of this subclass, unspecified or not relevant for measuring contours or curvatures, e.g. determining profile
G06F 111/20 - Configuration CAD, e.g. designing by assembling or positioning modules selected from libraries of predesigned modules
An apparatus includes a valve coupled to a pressure-containing component of a wellhead assembly. The pressure-containing component can include a hollow body, a bore within the hollow body, and an access passage that is in the hollow body and is in fluid communication with the bore. The valve can include a sealing element that is positioned along the access passage and is selectively moveable between closed and open positions to control fluid flow through the access passage. During operation, the sealing element may be moved between the closed and open positions without actuating the sealing element through an outer end of the access passage. Additional systems, devices, and methods are also disclosed.
A blowout preventer for shearing structures positioned in a bore extending through the blowout preventer, the blowout preventer body having a bore and guideways, first and second rams movably positioned relative the guideways and movable toward the bore, a blade of the first ram having a flat side, a blunt leading contour, an upper inclined surface forming an angle of about 140 degrees with the flat side, and a lower declined surface forming an angle of about 80 degrees with the at least one upper inclined surface, a blade of the second ram having a flat side, a leading contour, and at least one lower declined surface.
A blowout preventer (BOP) includes a main body comprising a bore extending therethrough and a pair of opposing upper and lower rams configured to shear a tubular extending through the bore. The upper ram includes a first sloped surface oriented crosswise to a vertical axis, the lower ram comprises a second sloped surface oriented crosswise to the vertical axis, and the first sloped surface and the second sloped surface are parallel to one another.
A blowout preventer (BOP) includes a main body that includes a bore extending therethrough and opposing shear rams configured to shear a tubular positioned within the bore. The opposing shear rams are configured to guide the tubular to be positioned within the bore in one of a plurality of recesses of the opposing shear rams upon engagement between the tubular and the opposing shear rams.
A mast for a drilling rig and a method for operation thereof, in which the mast includes a first leg, a second leg, and a mast leg actuator coupled to the first leg and the second leg. The mast leg actuator is configured to expand so as to pivot the first and second legs apart, and the mast leg actuator is configured to collapse so as to pivot the first and second legs together.
A valve gate assembly with a eutectic implement configured to degrade in response to a force imparted along a non-parallel load path. The unique architecture employed for various embodiments ensures a non-parallel load path is employed in triggering the shift in position for a valve gate. This enhances the integrity of the eutectic implements such that a wider variety of valve gate assembly dimensions may be utilized. This, in turn, allows for such assemblies to be utilized with larger production line volumes without compromise to safety measures afforded by such safety valves.
An apparatus includes a valve having a hollow body and an inner sealing assembly positioned in the hollow body. The inner sealing assembly includes a piston and can be moved between an open position and a closed position to selectively control flow along a flow path through the valve. The flow path includes a bore of the piston that allows flow through the piston, and pressure within the valve from a fluid in the flow path within the valve biases the inner sealing assembly toward the closed position to stop flow through the valve. Additional systems, devices, and methods are also disclosed.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
A tool joint assist system for making and breaking pipe joints of tubulars in a drill string relative to an onshore or offshore drilling rig, the tool joint assist system comprising a height indicator that is observable by an operator relative to the tubulars; a height adjustment input device operable by the operator; a mover of the height indicator; and a computer comprising a processor, a non-transitory storage medium, a transmitter/receiver, and a set of computer readable instructions stored in the non-transitory storage medium and when executed by the processor: (i) receive an input from the height adjustment input device to move the vertical position of the height indicator relative to the tubulars; (ii) and transmit a command to the mover of the height indicator to move the height indicator to the instructed vertical position.
A remote locking system for a blowout preventer (BOP) includes a locking mechanism configured to move to adjust the remote locking system between an unlocked configuration in which the remote locking system enables movement of a ram of the BOP and a locked configuration in which the remote locking system blocks movement of the ram of the BOP. The remote locking system also includes a gear assembly coupled to the locking mechanism, a motor coupled to the gear assembly, and an electronic controller configured to provide a control signal to activate the motor to drive the locking mechanism to move via the gear assembly.
A system that includes a wellhead. The wellhead defines a bore. A hanger system is positioned within the wellhead. The hanger system includes a piston angled relative to a longitudinal axis of the bore. A first spring biases the piston in a first direction. The piston contacts a slip segment to couple the slip segment to a casing string.
A technique facilitates drilling operations by combining a conductor with a conductor sharing offset shoe system. The conductor sharing offset shoe system protects against collision of boreholes by properly positioning and/or orienting a drill string during drilling of boreholes through the conductor. The conductor sharing offset shoe system may comprise a bullnose disposed at a lower end of the shoe system and an upper guide member disposed at an upper end of the shoe system with a guide opening sized to receive the drill string therethrough. A guide tubing extends from the guide opening into the bullnose to guide the drill string during drilling of a borehole. The guide tubing is sized to preserve sufficient space for accommodating movement of the drill string through the conductor sharing offset shoe system externally of the guide tubing during drilling of another borehole.
A system that includes a hanger orientation system that orients a tubing hanger within a wellhead. The hanger orientation system includes a conduit defining a first end and a second end opposite the first end. A sleeve couples to the conduit. The sleeve defines a spiral groove that engages a pin to rotate the tubing hanger.
An assembly for a blowout preventer includes a ram having a threaded opening. The assembly also includes a threaded shaft to engage the threaded opening and a motor to drive rotation of the threaded shaft. Rotation of the threaded shaft causes the ram to move axially along the threaded shaft.
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 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 pipe racking system including two mechanical arms to move pipe stands to a dedicated position on a rig floor wherein at least one mechanical arm is connected to a mast of a drilling rig. A method to move a drilling rig comprising: providing a pipe racking system with two mechanical arms connected to the mast of the drilling rig; folding the pipe racking system onto the mast of the drilling rig; and transporting the drilling rig without disassembling the pipe racking system from the mast.
A guide arm with dual guiding functionality is disclosed. The guide arm comprises two parallelogram mechanisms with a slew drive in between. The first parallelogram mechanism may move the guide arm between different travel positions. The slew drive may rotate the second parallelogram mechanism between different clock positions. The second parallelogram mechanism may extend and retract the guide arm. The guide arm may be mounted to a belly board or to a derrick wall rather than on a drill floor. A first guiding functionality may include guiding the lower end of a pipe stand in transfer between a drilling rig well center and a storage position. A second guiding functionality may include guiding the pin end of a single tubular between a drilling operation and a catwalk.
