An apparatus for inspection of a target asset comprises a drone including a body, one or more propellers coupled to the body that enable the drone to fly, and an electronic control unit coupled to or positioned within the body of the drone and coupled to the one or more propellers. The apparatus also comprises a neutron emission source and a neutron detector that are both coupled to the body of the drone and also communicatively coupled to the electronic control unit. The electronic control unit is configured to control navigation of the drone to reach the target asset, to activate the neutron emission source to radiate neutrons onto the asset and to gather data from the neutron detector which detects neutrons backscattered from the asset, indicative of a state of the asset and materials contained within the asset.
A method for optimizing drilling performance of a drilling operation is discloses. The method includes determining, while advancing a drill bit during the drilling operation based on drilling parameters specified by a user, a rate of penetration (ROP), acquiring, using sensors disposed throughout a rig of a well, sensor measurement data related to circulation of drilling fluid, generating, using a drilling hydraulics model based on at least the sensor measurement data of the circulation of drilling fluid, modeled rig and bit hydraulics data, displaying, on a driller console of the rig, the modeled rig and bit hydraulics data as a real-time drilling hydraulics profile, in response to a user viewing the displayed real-time drilling hydraulics profile, receiving an adjustment to the drilling parameters from the user, and further performing the drilling operation based on the adjustment to optimize the ROP.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
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 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
A wellbore completion assembly for anchoring a progressive cavity pump in a wellbore having a production tubing. The wellbore completion assembly includes a progressive cavity pump, an anchor, and an electrical submersible pump motor. The progressive cavity pump is configured to be disposed in a wellbore. The anchor is coupled to a downhole end of the progressive cavity pump to couple the progressive cavity pump to a production tubing positioned in the wellbore. The anchor has a body, a mechanical lock receiving assembly, and a seal. The body is coupled to the progressive cavity pump. The mechanical lock receiving assembly is positioned on a first external surface of the body to couple the body to the production tubing. The seal is positioned about the body to engage the production tubing. The electrical submersible pump motor is mechanically coupled to the progressive cavity pump by a drive shaft.
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 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A computer-implemented method for automated decline curve and production analysis using automated production segmentation, empirical modeling, and artificial intelligence. The method includes segmenting historical production data based on a change in a central tendency of a selected segmentation parameter to generate segmented production data. The method also includes forecasting future production data from a last production segment to a terminal decline rate according to a fitted empirical model, a trained artificial intelligence model, or any combinations thereof. The method includes forecasting exponential production data to an economic limit. Further, the method includes calculating an estimated ultimate recovery by summing the historical production data, future production data, and the exponential production data.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A system and method for treating sour water, including flowing sour water and a stripping agent in a countercurrent flow with respect to each other in a sour water stripper column to remove hydrogen sulfide from the sour water into the stripping agent to give treated water, discharging the spent stripping agent (having the hydrogen sulfide) from the sour water stripper column through an ejector to an injection compressor, and injecting the spent stripping agent into a hydrocarbon reservoir.
C02F 1/20 - Treatment of water, waste water, or sewage by degassing, i.e. liberation of dissolved gases
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
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
A cutter system for a polycrystalline diamond compact (PDC) drill bit includes a body; a static blade attached to the body; a translatable blade attached to the body; and at least one PDC cutting structure attached to the translatable blade. The translatable blade is configured to be translated and maintained in a translated position. The body includes a cavity cooperatively positioned angularly away from the static blade. The translatable blade translates into the cavity. The translatable blade has a substantially retracted rest position and a substantially extended rest position. The cavity includes a restricting device within said cavity, so that said restricting device engages said translatable blade member in the substantially retracted position or the substantially extended position.
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
A magnetic downhole monitoring system includes a sensor configured to be lowered into a wellbore and to sense a well parameter. The sensor is housed in a magnetic material. A magnetic joint is configured to be attached to an inner surface of a wellbore tubular installed within a wellbore completion. The magnetic joint is configured to be electromagnetically activated to attract and attach to the sensor. A power cable is configured to be lowered into an annulus between the wellbore completion and the wellbore tubular. The power cable is configured to provide power through the wellbore tubular to electromagnetically activate the magnetic joint.
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
Provided is hydrocarbon reservoir production system and method that employs a production monitoring system including a well production monitoring system to obtain well production data and gas characteristics of hydrocarbons produced by wells associated with a production region of the reservoir. The production monitoring system adapted to receive selection of modeling parameters, including a selected region and time period, and to generate a set of well performance data including a production data and gas production data for the selected region and time period. A production modeling system adapted to generate, based on the set of well performance data, a model of the performance of the selected region. A production operations system adapted to regulate, based on simulation of the model, operation of wells in the selected region.
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
E21B 41/00 - Equipment or details not covered by groups
9.
METHOD AND SYSTEM FOR MANAGING APPROVAL WORKFLOW PROCESSES IN A NETWORK SYSTEM
Coordination and management of workflows in parallel among a plurality of approval applications executing on machines within an enterprise network by receiving, at a central location, workflows from an initiating application, determining a set of approvals for each respective workflow and respective approval routes, performing an initial distribution of the respective workflows from the central location by propagating the workflows across their respective approval routes to respective members of the set of approval applications, applying at respective approval applications a set of approval rules to the workflow to determine a workflow’s approval status as either approved or rejected, returning the workflow’s approval status to the initiating application via the central location, and performing one or more follow-up distributions of workflows from the central location until either all approval applications indicate a status of approved or a number of follow-up distributions reaches a pre-defined maximum number of follow-up distributions.
A computer-implemented method that enables dew point pressure prediction using isothermal constant composition expansion and artificial intelligence is described herein. The method includes obtaining constant composition expansion data of a reservoir fluid, and predicting saturation pressures for the reservoir fluid at the constant composition expansion data points using a trained machine learning model selected from multiple machine learning models that are trained using data from a generated constant composition expansion library. The method also includes determining a central tendency of the predicted saturation pressures to obtain a final saturation pressure corresponding to the constant composition expansion data for the reservoir fluid. In examples, the final saturation pressure is a dew point pressure of the reservoir fluid
A diagnostics and control system (DCS) for an artificial lift system (ALS) in a well, comprising: a sensor network comprising a plurality of sensors for monitoring and obtaining measurements at a power source of the ALS and at a downhole pump of the ALS; a conditioning subsystem configured to measure ALS system performance data; a processing subsystem configured to receive communications from the conditioning subsystem and comprising a processor configured to process sensor data obtained by the sensor network; and a permanent local wellsite monitor that is controlled by the processing subsystem and is powered using a production controller of the ALS, wherein the permanent local wellsite monitor comprises a central surveillance center for transmitting commands and coordinating testing of the ALS among the sensor network, the conditioning subsystem, and the processing subsystem; wherein a condition of the ALS is evaluated by the permanent local wellsite monitor using the processed sensor data, testing results and system performance data to monitor a health of the ALS.
An apparatus for inspection of a target asset comprises a drone including a body (110), one or more propellers (115) coupled to the body that enable the drone to fly, and an electronic control unit (210) coupled to or positioned within the body of the drone and coupled to the one or more propellers. The apparatus also comprises a neutron emission source (120) and a neutron detector (130) that are both coupled to the body of the drone and also communicatively coupled to the electronic control unit. The electronic control unit is configured to control navigation of the drone to reach the target asset, to activate the neutron emission source to radiate neutrons onto the asset and to gather data from the neutron detector which detects neutrons backscattered from the asset, indicative of a state of the asset and materials contained within the asset.
G01T 7/00 - MEASUREMENT OF NUCLEAR OR X-RADIATION - Details of radiation-measuring instruments
G01V 5/02 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for surface logging, e.g. from aircraft
G01N 23/204 - Measuring back scattering using neutrons
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Liu, Lu
Qin, Fuhao
Luo, Yi
Li, Yubing
Abstract
A method of determining a presence of hydrocarbons, includes the following steps: obtaining a surface seismic dataset, composed of a plurality of seismic gathers (402), determining a redatumed gather for a target horizon based on the seismic gather (404), determining a time window of the redatumed gather around the target horizon (406), determining a spectrum of a portion within the time window (408), determining a hydrocarbon indicator based, at least in part, on an amplitude of a higher-frequency portion and lower-frequency portion of the spectrum of the plurality of seismic gathers (410), determining a geographic map of values of the hydrocarbon indicator from the plurality of seismic gathers (510), and determining a presence of hydrocarbons based, at least in part, on at least one anomalous value on the geographic map (414). A system and a non-transitory computer readable medium storing instructions are also disclosed.
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
Inventor
Desouky, Mahmoud H.
Aljawad, Murtada Saleh
Solling, Theis
Altammar, Murtadha J.
Alruwaili, Khalid Mohammed
Abstract
A method for stabilizing a wellbore includes introducing a hardening agent into the wellbore, mixing the hardening agent with a carrier fluid in the wellbore to produce a wellbore stabilizing fluid, and treating a wellbore wall of the wellbore by contacting the wellbore stabilizing fluid to a surface of the wellbore wall for at least 48 hours. A wellbore stabilizing fluid includes a hardening agent and a carrier fluid. The hardening agent is selected from one of 10 to 100 g/L of the calcium hydroxide nanocrystals, 5 to 99.9% by volume of tetraethyl orthosilicate (TEOS), and 10 to 50 g/L of zinc sulfate. A stabilized wellbore includes a wellbore having a wellbore wall treated with a wellbore stabilizing fluid comprising a hardening agent. The Young's modulus of the treated wellbore wall is at least 5% higher than a Young's modulus of a non-treated wellbore wall.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/44 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing organic binders only
An alkanolamine gas treatment unit system that may comprise an absorber column, a regenerator column, and a once-through natural circulation vertical thermosyphon reboiler comprising a reboiler tube and a shell. The reboiler may be a steam driven one having a process side and a shell side, wherein the process side is inside the reboiler tube, the process side of the reboiler and the regenerator column are in fluid communication with one another, an inner surface of the reboiler tube, on the process side, has a surface roughness of 0.06 µm or greater, the shell side of the reboiler is in fluid communication to a steam source, and the regenerator column and the absorber column are in fluid communication with one another. An absorbent regenerator system that may comprise the regenerator column and the once-through natural circulation vertical thermosyphon reboiler.
B01D 3/32 - Other features of fractionating columns
B01D 53/14 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 3/26 - Fractionating columns in which vapour and liquid flow pass each other, or in which the fluid is sprayed into the vapour, or in which a two-phase mixture is passed in one direction
16.
MODEL PREDICTIVE CONTROL SYSTEM AND METHOD USING NEURAL NETWORK TO CONTROL DISSOLVED OXYGEN AND PH IN SEAWATER
A system and method for model predictive control of a process for removing dissolved oxygen (DO) from seawater to produce treated seawater having less than a prescribed DO concentration and a prescribed pH is disclosed. The model predictive control system includes a machine learning (ML) module for calculating, based on the values of operational input parameters, a predicted DO concentration and a predicted pH of the treated seawater for a future point in time. An ML-based control module is configured to determine, based on the predicted DO concentration, predicted pH and the input parameters, settings for adjusting controllable operational input parameters that serve to change the DO concentration or pH of the treated seawater. The control system monitors DO and pH during operation to dynamically update the DO and pH predictions, and adaptively update system settings to produce treated seawater having less than the prescribed DO concentration and pH.
C02F 1/00 - Treatment of water, waste water, or sewage
G05B 13/02 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric
G05B 13/04 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric involving the use of models or simulators
C02F 1/68 - Treatment of water, waste water, or sewage by addition of specified substances, e.g. trace elements, for ameliorating potable water
This disclosure relates to demulsifier compositions containing one or more demulsifying polymers and an alkyl carboxylic acid solvent, and methods of using the compositions for separating water-in-oil emulsions.
A method and systems for evacuating a building during an incident are provided. An exemplary method includes tracking location of personnel in the building, monitoring incident sensors, detecting an incident based, at least in part, on the incident sensors, activating alert systems, locating unevacuated personnel in the building, and displaying the location of the unevacuated personnel on a fire alarm control panel (FACP).
A method and a system for separating an oil-in-water emulsion in a water-oil separation plant (WSOP) are provided. An exemplary method includes feeding the oil-in-water emulsion to the WSOP, and forcing the oil-in-water emulsion through a silica sand filter to separate the oil and form a separated water stream.
Lost circulation material (LCM) compositions may include a resin; an emulsifier selected from the group consisting of ethoxylated phenol, sodium salt of modified tall oil fatty amide, carboxylic acid terminated fatty polyamide, modified amidoamine, tall oil fatty acid, oxidized tall oil fatty amidoamine, ether carboxylic acid, and combinations thereof; a crosslinker; a cementitious and/or weighting agent; a retarder; a dispersant; and a silicon-based defoamer. The LCM compositions may have a thickening time of from about 3 hours than about 6 hours by reaching a Bearden consistency of 100 Bc. Methods of eliminating or reducing lost circulation in a lost circulation zone from a well may include introducing these LCM compositions into the well.
C09K 8/512 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
C09K 23/00 - Use of substances as emulsifying, wetting, dispersing, or foam-producing agents
C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
21.
Subsurface safety valve operation monitoring system
A system includes a subsurface safety valve assembly connected to a production tubing string and including a sensor assembly disposed on its outer surface. The sensor assembly includes a magnetic sensor configured to measure a magnetic field or a sonic sensor configured to measure a sonic signal, and is configured to measure a change in a parameter caused by change in position of a closure member that is configured to selectively permit fluid flow through the central bore of the subsurface safety valve. The system further includes a control unit positioned at a surface location and that is configured to receive, from sensor assembly, a measurement of the change in the parameter, wherein the measurement is a change in the magnetic field or a change in the sonic signal.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A gauge carrier protective housing is provided including attributes that improve the overall structural integrity and minimizes the likelihood of damage to the sensors, including shock absorbing elements, and a protective tubular structure encasing a gauge carrier holding the one or more sensors.
B01J 20/28 - Solid sorbent compositions or filter aid compositions; Sorbents for chromatography; Processes for preparing, regenerating or reactivating thereof characterised by their form or physical properties
B01D 53/14 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
King Fahd University of Petroleum and Minerals (Saudi Arabia)
Inventor
Akah, Aaron Chi
Qureshi, Ziyauddin S.
Aitani, Abdullah M.
Abdulbari, Siddiqui M.
Abstract
A process for upgrading a hydrocarbon feed includes contacting the hydrocarbon feed with steam in the presence of a cracking catalyst in a steam catalytic cracking reactor at reaction conditions sufficient to cause at least a portion of hydrocarbons in the hydrocarbon feed to undergo one or more cracking reactions to produce a steam catalytic cracking effluent comprising light olefins, light aromatic compounds, or both, where the cracking catalyst comprises a ZSM-11 zeolite.
C10G 45/12 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing crystalline alumino-silicates, e.g. molecular sieves
B01J 29/40 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the pentasil type, e.g. types ZSM-5, ZSM-8 or ZSM-11
B82Y 30/00 - Nanotechnology for materials or surface science, e.g. nanocomposites
A system includes hoisting cables for raising or lowering an oil rig mast, a support, and hoisting sheaves rotatably mounted on the support. The hoisting cables are wound at least in part about the hoisting sheaves during a process of raising or lowering the mast. Also included are measurement devices which measure angular displacement of the hoisting sheaves during a process of raising or lowering the mast with the hoisting cables. Further included is a signaling device which produces a signal if the measured angular displacement of the hoisting sheaves does not correspond to one or more reference values. A related method includes measuring angular displacement of the hoisting sheaves; comparing measured angular displacement of the hoisting sheaves with one or more reference values; and producing a signal if the measured angular displacement of the hoisting sheaves does not correspond to the one or more reference values.
Systems and methods include a computer-implemented method for verifying blockchain transaction. A request is received in a blockchain for a user to use an application. A three-blockchain cluster verification process is performed in response to receiving the request. Verification that the application is authorized is performed using a nodes blockchain cluster in the blockchain based on user-application data pre-verified by at least two administrators and stored in the nodes blockchain cluster. Verification that the user exists and is authorized is performed using a users/objects blockchain cluster in the blockchain different from the nodes blockchain cluster, where the verifying is based on the user-application data pre-verified by the at least two administrators and stored in the users/objects blockchain cluster. Verification that credentials for the user exist is performed using a passwords blockchain cluster in the blockchain different from the nodes blockchain cluster and the users/objects blockchain cluster, where the verifying is based on the user-application data pre-verified by the at least two administrators and stored in the passwords blockchain cluster. Access to the application is granted to the user in response to successfully completing the three-blockchain cluster verification process, including verification using the nodes blockchain cluster, the users/objects blockchain cluster, and the passwords blockchain cluster.
H04L 9/32 - Arrangements for secret or secure communications; Network security protocols including means for verifying the identity or authority of a user of the system
A method for determining flow rates and phase fractions within a throughbore is disclosed. The method includes providing a mixture of one or more fluids through a fluid flow path in a throughbore at a flow rate, reducing the flow rate, slidably moving a first and second sleeve along the throughbore to a first position of a plurality of positions, measuring a first and second differential pressure at the first position, calculating a first loss pressure ratio from the first and second differential pressure. The method further includes slidably moving the first sleeve and second sleeve to each of the others of the plurality of positions in succession after the first position, measuring a plurality of differential pressures and calculating a loss pressure ratio at each of the plurality of positions, and calculating a plurality of flow rates phase fractions of the fluids flowing through the fluid flow path.
G01F 1/40 - 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 measuring pressure or differential pressure the pressure or differential pressure being created by the use of flow constriction - Details of construction of the flow constriction devices
G01N 9/26 - Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity by measuring pressure differences
28.
OPERATIONAL OPTIMIZATION OF INDUSTRIAL STEAM AND POWER UTILITY SYSTEMS
Operational optimization of an industrial plant that implements steam and power systems and that includes multiple equipment including a cogeneration system and a steam turbine includes, for each equipment, a computer system receives, during operation of each equipment, measured operational physical parameter values output by the equipment during operation. The computer system determines mass balance and energy balance parameters associated with the equipment using the received operational physical parameter values. The computer system validates an operation of the equipment using the determined mass balance and energy balance parameters. After validating mass balance and energy balance parameters for all the equipment, the computer system determines mass balance and energy balance parameters associated with the industrial plant using the parameters for each equipment. The computer system validates an operation of the plant using the determined mass balance and energy balance parameters associated with the industrial plant.
This disclosure relates to slurry-phase catalyst compositions comprising a metal complex and disulfide oil, and methods of making said compositions in slurry-phase hydrocracking units.
Electrical cables are attached to an outer surface of production tubing. The electrical cables are configured to be connected at a first end to a topside electrical power supply. Electrical contacts are attached to a second end of the electrical cables. The contacts are at a downhole end of the production tubing.
Mesoporous silica is disclosed possessing a two-dimensional, hexagonal, through-hole structure with a space group p6mm, that is formed using one or more water-soluble oxidized disulfide oil (ODSO) compounds during the synthesis to impart distinct characteristics including an increased percentage of silanol groups.
C01B 33/193 - Preparation of finely divided silica neither in sol nor in gel form; After-treatment thereof by acidic treatment of silicates of aqueous solutions of silicates
A system and methods for determining a refined seismic model of a subterranean region are disclosed. The method includes obtaining an observed seismic dataset and a current seismic model for the subterranean region and training a machine learning (ML) network using seismic training models and corresponding seismic training datasets and predicting, using the trained ML network, a predicted seismic model from the observed seismic dataset. The method further includes determining a simulated seismic dataset from the current seismic model and a seismic wavelet, a data penalty function based on a difference between the observed and the simulated seismic datasets and a model penalty function from the difference between the current the predicted seismic models. The method still further includes determining the refined seismic model based on an extremum of a composite penalty function based on a weighted sum of the data penalty function and the model penalty function.
G01V 99/00 - Subject matter not provided for in other groups of this subclass
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
33.
UTILIZING CONCENTRATED SOLAR POWER FOR WATER-OIL SEPARATION
Systems and processes for water-oil separations include feeding an oil-water mixture to an inlet of a water-oil separation vessel for separation of the decontaminated water from the oil. Steam bubbles are used to facilitate the separations, where the systems and processes include a water circulation loop for circulating a portion of the decontaminated water through the water circulation loop and heating the water to generate steam via solar energy captured by the concentrated solar collector. The steam may then be fed to a distributor in a separation chamber of the water-oil separation vessel, the distributor distributing the steam in the separation chamber of the water-oil separation vessel as a plurality of bubbles, facilitating separation of oil from water.
Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on laser induced fluorescence spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.
A process for the determining of sweet spot intervals based on a combination of rock quality, an in-situ stress regime, natural fractures, and the identification of fluid flow paths from the interaction of hydraulic fracturing and formation attributes. The process may include determining geological components, determining mechanical earth model outputs, and determining sweet spot intervals using additional data from fracture calibration tests. Systems and computer-readable media for the determining of sweet spot intervals are also provided.
Systems and methods for developing a reservoir that include obtaining well log data (conducting nuclear magnetic resonance (NMR), gamma ray (GR), and resistivity logging operations to generate corresponding NMR, GR and formation true resistivity logs for one or more wells in the reservoir), determining rock property data based on the well log data, determining a “water-zone baseline” based on the rock property data (e.g., based on a cross-plot of rock properties determined from the NMR and GR logs and resistivity values), and determining water saturation data based on the water-zone baseline.
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
G01V 3/14 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electron or nuclear magnetic resonance
G01V 5/06 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging for detecting naturally radioactive minerals
G01V 3/02 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with propagation of electric current
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
37.
METHOD FOR PREDICTING A GEOPHYSICAL MODEL OF A SUBTERRANEAN REGION OF INTEREST
A system and methods are disclosed for determining a model of a subterranean region. The method includes obtaining an observed dataset and a current model for the subterranean region, simulating a dataset from the current model, and determining a data penalty function based on a difference between the observed and simulated datasets. The method further includes training a machine learning (ML) network to predict a model from the observed dataset and determining the predicted model using the trained ML network. The method further includes determining a first model penalty function based on the current model, a second model penalty function based on a difference between the current and the predicted models, and a composite penalty function based on a weighted sum of the data penalty function, the first and the second model penalty functions. Finally, the method includes determining the model based on an extremum of a composite penalty function.
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
38.
PEPTIZATION AGENT AND SOLID CATALYST MANUFACTURING METHOD
Methods of solid catalyst manufacture using a a peptization agent, and formed solid catalyst materials having improved structural properties are provided. The peptization agent includes one or more oxidized disulfide oil ("ODSO") compounds. These ODSO compounds peptization agents serve to improve the adhesion characteristics of the binder material, and as a result increase the particle strength of the final catalyst particles.
Operational optimization of an industrial plant that implements steam and power systems and that includes multiple equipment including a cogeneration system and a steam turbine includes, for each equipment, a computer system receives, during operation of each equipment, measured operational physical parameter values output by the equipment during operation. The computer system determines mass balance and energy balance parameters associated with the equipment using the received operational physical parameter values. The computer system validates an operation of the equipment using the determined mass balance and energy balance parameters. After validating mass balance and energy balance parameters for all the equipment, the computer system determines mass balance and energy balance parameters associated with the industrial plant using the parameters for each equipment. The computer system validates an operation of the plant using the determined mass balance and energy balance parameters associated with the industrial plant.
F01K 13/02 - Controlling, e.g. stopping or starting
40.
METHODS AND SYSTEMS FOR CEMENTED OPEN HOLE INTELLIGENT COMPLETIONS IN MULTILATERAL WELLS REQUIRING FULL ISOLATION OF GAS CAP, FRACTURES AND / OR WATER BEARING BOUNDARIES
A method of providing a cemented open hole intelligent completion in a well containing an open hole having a perimeter in which plurality of laterals are embedded. The method comprises deploying a first string section in a portion of the open hole containing the plurality of laterals, the first section having intelligent completion components including control valves, gauges and control lines operable from a surface station, deploying a second string section coupled to and positioned above the first string section and above the plurality of laterals including a setting packer, and delivering cement downhole that sets in a cemented section comprising an annulus between the second string and the perimeter of the open hole. The cemented section is positioned above the plurality of laterals so as to block fluids from production while not interfering with communication between the surface and the intelligent components of the first string.
Systems and methods for measuring pH of a drilling fluid in a downhole drilling environment are disclosed. The system includes wireless pH sensing devices dispersed in the drilling fluid and circulated through a borehole. The wireless pH sensing devices include a capsule shell for protecting internal electronics from harsh downhole conditions. The electronics include an electrolyte insulator semiconductor field-effect (EIS) pH sensor structure, a controller, RF communications unit and power supply. The pH sensing devices periodically measure the pH of the fluid while circulating through the borehole. Upon return of the sensors above ground, the pH measurements are wirelessly provided to a monitoring computer, prior to recirculating the sensors through the borehole.
Methods of solid catalyst manufacture using a peptization agent, and formed solid catalyst materials having improved structural properties are provided. The peptization agent includes one or more oxidized disulfide oil (“ODSO”) compounds. These ODSO compounds peptization agents serve to improve the adhesion characteristics of the binder material, and as a result increase the particle strength of the final catalyst particles.
A system and methods for determining an updated geophysical model of a subterranean region of interest are disclosed. The method includes obtaining a preprocessed observed geophysical dataset based, at least in part, on an observed geophysical dataset of the subterranean region of interest, and forming a training dataset composed of a plurality of geophysical training models and corresponding simulated geophysical training datasets. The method further includes iteratively determining a simulated geophysical dataset from a current geophysical model, determining a data loss function between the preprocessed observed geophysical dataset and the simulated geophysical dataset, training a machine learning (ML) network, using the training dataset, to predict a predicted geophysical model and determining a model loss function between the current and predicted geophysical models. The method still further includes updating the current geophysical model based on an inversion using the data loss and model loss functions.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
44.
Transient Pressure Data Analysis to Determine Contributing Inflow Control Devices
A computer-implemented method, medium, and system for determining contributing inflow control devices (ICDs) using transient pressure data from a permanent downhole monitoring system (PDHMS) in a wellbore is disclosed. One example computer-implemented method includes receiving transient pressure data from a PDHMS in the wellbore. Multiple ICDs are installed in the wellbore and include multiple contributing ICDs that contribute to fluid flow in the wellbore. Curve fitting of multiple composite exponential signals is performed to match the transient pressure data. A total number of the multiple contributing ICDs is determined based on a result of performing the curve fitting. A respective normalized distance between each pair of adjacent ICDs of the multiple contributing ICDs is determined. A depth of a last ICD in the multiple contributing ICDs is determined. A list of all contributing ICDs is generated based on the determination of the depth of the last ICD.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/09 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes
45.
Removing the Effect of Near-Surface Inhomogeneities in Surface-to-Borehole Measurements
Systems and methods for removing galvanic distortion caused by near-surface inhomogeneities from surface-to-borehole (STB) measurements are disclosed. Corrected STB measurements may provide for a representation of the resistivity of an oil-bearing reservoir and may be used to determine movement of a waterfront within the reservoir caused by waterflooding of the reservoir.
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
G01V 1/38 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 3/08 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
An assembly includes a bypass line having a first connection end and a second connection end, a device base positioned along the bypass line, an upstream valve positioned along the bypass line between the device base and the first connection end, and a downstream valve positioned along the bypass line between the device base and the second connection end. The device base includes a first opening to the bypass line, a second opening to the bypass line, and a support structure supporting at least one of the first and second openings.
G01N 11/04 - Investigating flow properties of materials, e.g. viscosity or plasticity; Analysing materials by determining flow properties by measuring flow of the material through a restricted passage, e.g. tube, aperture
G01N 1/20 - Devices for withdrawing samples in the liquid or fluent state for flowing or falling materials
47.
ISOLATED ELECTRICAL SUBMERSIBLE PUMP (ESP) MOTOR TERMINATION
A completion configuration and a method for an electrical submersible pump (ESP) are provided. An exemplary completion configuration includes a dual port packer, a tubing line mounted in a first port of the dual port packer, wherein the tubing line carries fluid from a reservoir to a surface, and a motor head mounted in a second port of the dual port packer, wherein the motor head couples to ESP power terminations that are disposed uphole of the dual port packer.
A downhole tool includes a main body configured to be disposed by a conveyance member within a tubing string disposed in a wellbore drilled into a subterranean zone, and a plurality of hammers disposed about a central axis of the main body, each of the plurality of hammers configured to reciprocate radially with respect to the central axis. The tool also includes a plurality of electric motors, each of the plurality of electric motors configured to drive the reciprocation of a respective one of the plurality of hammers, such that each of the electric motors can cause a respective hammer to repetitively strike an interior surface of the tubing string and thereby impart vibration in the tubing string.
A gas separation membrane, methods of forming the membrane, and methods of using the membrane for gas separation are provided. An exemplary gas separation membrane includes a cellulosic matrix and a polymer of intrinsic microporosity (PIM). The PIM includes chains coupled by a heat-treating under vacuum.
B01D 53/22 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by diffusion
B01D 69/02 - Semi-permeable membranes for separation processes or apparatus characterised by their form, structure or properties; Manufacturing processes specially adapted therefor characterised by their properties
B01D 67/00 - Processes specially adapted for manufacturing semi-permeable membranes for separation processes or apparatus
A temporary trap door cap device for sealing around a pressure-leaking trap door at an end of a pipeline terminating in a trap includes a canister formed from a longitudinally extending pipe having an open end and a closed end; and an annular rim connected to the open end, with an inner diameter smaller than an inner diameter of the canister. The annular rim is configured such that the inner diameter of the annular rim fits over the trap door of the trap terminating the pipeline. After the annular rim has passed over the trap door, the inner diameter of the annular rim is compressible against a body of the trap terminating the pipeline so as to seal an inner volume of the canister pressure-tight thereby containing the trap door within the pressure-tight volume.
Systems include a floating device disposed on a top of a column of drilling fluid in an annulus of a wellbore. The floating device includes a capsule. A transmitter or a reflector may be coupled to the capsule. The floating device may transmit signals to a surface region from the annulus or receive signals from the surface region and reflect at least a portion of the received signals. A receiver in the surface region receives transmitted signals or reflected signals from the floating device and determines a distance between the floating device and a reference point in the surface region. The distance indicates a level of the drilling fluid in the annulus.
G01F 23/68 - Indicating or measuring liquid level or level of fluent solid material, e.g. indicating in terms of volume or indicating by means of an alarm by floats of the free float type using electrically actuated indicating means
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 geological core inspection system that includes a table to support core samples for inspection, a robotic geological core inspection system including a core sample sensing system to acquire sample inspection data (including an imaging sensor and a core sample position sensor), a core sample interaction system (including a dispensing system and a scoring system), and a robotic positioning system, and a control and communications system to provide for remote control of the core sample sensing system. The system further including a remote geological core inspection system to receive and communicate remote commands specifying requested operations of the robotic geological core inspection system (the control and communications system adapted to control operation of the core sample sensing system in response to the remote commands to perform the requested operations) and receive and present core data.
A rotatable plate is configured to be coupled to a rotary table of a rig floor. The rotatable plate defines a central passage through which a tubular can be passed. Multiple arms each have a first end rotably coupled to the rotatable plate. The arms are hinged such that a distal end of the arms, away from the rotatable plate, are configured to move towards or away from the passage. Each of arms extends away from the rotatable plate towards the passage. The arms are biased away from the passage. Rollers are rotably coupled to one of the distal ends of the arms.
An apparatus for applying pressure to a pipe and measuring internal pressure. The apparatus including jacket disposed on the pipe, one or more of a first set of strain gauges disposed on a wall of the pipe, one or more of a second set of strain gauges disposed on the wall of the pipe, and a temperature sensor disposed on the wall of the pipe. The pipe has an inner diameter, an outer diameter, and a length.
G01B 5/30 - Measuring arrangements characterised by the use of mechanical techniques for measuring the deformation in a solid, e.g. mechanical strain gauge
G01B 5/00 - Measuring arrangements characterised by the use of mechanical techniques
F16B 2/06 - Clamps, i.e. with gripping action effected by positive means other than the inherent resistance to deformation of the material of the fastening external, i.e. with contracting action
55.
AUTONOMOUS PRESSURE TRIGGERED WELL LIVENING TOOL WITH EXOTHERMIC NITROGEN PRODUCING CHEMISTRY
A wellbore tool may include a port through the body and a first rupture disk disposed on the body and covering the port, the body defining a first interior chamber and a second interior chamber, with a liquid-permeable membrane separating the first interior chamber and the second interior chamber within the body. The body may be configured to retain a first solid reactant in the first interior chamber and a second solid reactant in the second interior chamber, wherein the first rupture disk is configured to rupture at a pressure differential downhole. A method for livening a well may include lowering the wellbore tool into a wellbore.
An apparatus for transporting a clastic rock sample including a palynomorph includes a housing, a reaction vessel, multiple rods, a lid, a pressure release tubing, and a spill neutralization padding. The reaction vessel is disposed within the housing. The reaction vessel is configured to hold a specified quantity of hydrofluoric acid and the clastic rock sample. The rods extend from the housing to the reaction vessel. The lid is configured to seal against the reaction vessel to isolate an inner volume of the reaction vessel from an external environment. The pressure release tubing is configured to couple to a pressure relief valve and establish fluid communication between the annular volume and the pressure relief valve. The spill neutralization padding is configured to react with the hydrofluoric acid in an acid-base neutralization reaction in response to coming in contact with the hydrofluoric acid.
A system for analyzing a multiphase production fluid, the system including a pipeline, an inlet divider having a set of analyzing apertures with densitometers and a set of production apertures, a fluidic separation chamber with flowmeters, a pressure control valve, and a fluidic control unit. Each analyzing aperture of the set of analyzing apertures disposed on a vertically-oriented axis of the inlet divider. The pipeline is configured to supply the multiphase production fluid to the inlet divider. The inlet divider is configured to provide an analysis portion of the multiphase production fluid to the set of analyzing apertures. The inlet divider is configured to provide a production portion of the multiphase production fluid to the set of production apertures. The set of analyzing apertures is configured to provide the analysis portion to the fluidic separation chamber.
A wellbore assembly includes a drill string, a drill bit, and a reamer assembly. The reamer assembly is coupled to the drill string uphole of the drill bit and includes a side cutter. The reamer assembly includes a spring that moves the side cutter from an extended position, in which the side cutter is retained by a portion of the reamer assembly against inward movement and in which the cutter defines a first drilling diameter greater than a drilling diameter of the drill bit, to a retracted position in which the portion of the reamer assembly has been broken by a shear force applied by the side cutter under a weight on bit applied against an inner component of the casing. In the retracted position, the side cutter is housed within the housing and defines a drilling diameter equal to or less than the drilling diameter of the drill bit.
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 10/30 - Longitudinal axis roller reamers, e.g. reamer stabilisers
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 10/34 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools of roller-cutter type
59.
FLOAT VALVE ASSEMBLY FOR DRILLING AND WORKOVER OPERATIONS
A float valve assembly is configured to be positioned within in a central bore of a tubular string disposed in a wellbore drilled into a subterranean zone. The float valve assembly includes a valve main body and a plunger, and the plunger is biased by a spring towards a closed position and is configured to open in response to a fluid pressure in a downhole direction. The surface of the plunger main body includes a plurality of substantially flat lateral faces forming a pyramid. A hydrophilic nano-coating comprising particles with sizes of between 1 and 100 nanometers is disposed on at least a portion of the surface of the plunger main body.
Disclosed is a system that includes a plurality of battery cells connected in series; a first connection path from an intermediate battery cell of the plurality to an output bus of the system; a second connection path from a last one of the plurality of battery cells to an output bus; a circuit switch installed along the second connection path, the circuit switch configured to open or close the second connection path; and an undervoltage relay in the output bus, wherein the undervoltage relay is set at a threshold voltage, and wherein the undervoltage relay is configured to control the circuit switch when a voltage on the output bus exceeds the threshold voltage or drops below the threshold voltage.
H02J 9/06 - Circuit arrangements for emergency or stand-by power supply, e.g. for emergency lighting in which the distribution system is disconnected from the normal source and connected to a standby source with automatic change-over
61.
PROPER LAYOUT OF DATA IN GPUS FOR ACCELERATING LINE SOLVE PRE-CONDITIONER USED IN ITERATIVE LINEAR SOLVERS IN RESERVOIR SIMULATION
A computer implemented method and system for simulating a hydrocarbon reservoir (302). The method includes determining a computational reservoir model, comprising formation data and fluid pressure data for each of a plurality of reservoir cells, and forming a tridiagonal matrix system for each of M strongly connected lines and arranging arrays of the M tridiagonal matrix systems in a level-based data layout (1500) to be stored in a memory (1806) of a graphical processing unit (GPU). The method further includes to determining, with the GPU, an unknown potential array for each of the tridiagonal matrix systems by solving the tridiagonal matrix systems simultaneously using a Thomas method configured to operate with the level -based data layout (1500).
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G06F 30/20 - Design optimisation, verification or simulation
Systems and methods include a computer-implemented method for managing crude oil demand at a crude oil processing plant. Real-time process data is received for the plant and includes quantitative values for conditions and operations at the plant. A multiple stabilizer oil flow control strategy is determined for crude oil stabilizer columns of the plant using the real-time process data. A targeted oil flow rate is determined for each stabilizer column using the strategy. The targeted oil flow rate provides a continuous and on-target crude oil supply to components of the plant in multiple operating scenarios. The on-target crude oil supply includes a range of oil flow volumes required for continuous operation. The plant is operated using the strategy, including maintaining, using the targeted oil flow rate for each stabilizer column, crude oil demand for different combinations of the crude oil stabilizer columns and multiple operating scenarios.
A system and method for oil and water separation of a crude oil composition are provided. The system includes a gravity dehydrator vessel, a heat exchanger upstream of the gravity of the dehydrator vessel, and a plurality of metallic grids located within the gravity dehydrator vessel. The system further includes a mesh metal structure within the gravity dehydrator vessel, a microwave generator operatively connected to the gravity dehydrator vessel, and a waveguide carrying microwave energy from the microwave generator. The system and method separate water and emulsions from the crude oil composition by forming an upper crude oil layer, a middle oil-water emulsion layer, and a lower oily water layer.
Systems and methods include a method for providing plots for challenges, successes, and failures in well completions. A challenges-successes-failures database is created from historical data collected from past well completions. The database identifies: 1) challenges encountered during well completions, 2) corresponding successes and failures, and 3) job parameters used during well completions. A dimension embedding algorithm is selected to represent the data. Hyper-parameter tuning is performed on the algorithm. The dimension embedding model is generated and added to a system pipeline for a new well completion job. Nonlinear dimension embedding algorithms are run against data points in the cleaned and processed data using the challenges-successes-failures database and new job parameters entered in a user interface. Scatter plots of two-dimensional (2D) points are generated and labeled with each point's job parameters.
A method for increasing CO2 sequestration efficiency in depleted reservoirs using a CO2 thickener is provided. The method may include the steps of introducing a thickened CO2 mixture into the depleted reservoir, where the thickened CO2 mixture comprises a mixture of CO2 and a CO2 thickener. The method may include using CO2 is in a liquid or supercritical state upon introduction into the depleted reservoir. The method may also include the step of using a CO2 thickener comprising a methyl acrylate-based copolymer, a CO2 solvent, and a solvent.
A separator apparatus includes an intake nozzle, first cyclone device, and a second cyclone device. The first and second cyclone devices each include an inlet section, a scroll, a barrel centered on a first axis, a vortex finder, and an underflow portion. The scroll is attached to the inlet section and to the barrel such that the scroll connects the inlet section to the barrel. The vortex finder has a vortex tube arranged concentrically on the axis in an interior volume of barrel. The underflow portion defines an annular gap in fluid connection with the interior volume. The intake nozzle is fluidly connected to the inlet sections of the first and second cyclone devices.
B04C 5/13 - Construction of the overflow ducting, e.g. diffusing or spiral exits formed as a vortex finder and extending into the vortex chamber; Discharge from vortex finder otherwise than at the top of the cyclone; Devices for controlling the overflow
B04C 5/181 - Bulkheads or central bodies in the discharge opening
METHOD, APPARATUS, AND SYSTEM FOR IDENTIFYING ONE OR MORE SOURCES OF AIR POLLUTANTS BASED ON EMISSION DATA FROM VEHICLES AND AIR QUALITY DATA FROM AMBIENT AIR MEASUREMENT APPARATUSES
An apparatus and a method for identifying one or more sources of an airborne pollutant in a geographical area and for mitigating release of the airborne pollutant, comprising: receiving emission data and vehicle location data associated with a plurality of corresponding vehicles in the geographical area; receiving ambient air quality data for respective locations in the geographical area; apply a vehicle emission plume air dispersion model to process the received emission data, the received vehicle location data, and the received ambient air quality data; identify one or more principal sources of the airborne pollutant based on the processed emission data, vehicle location data, and ambient air quality data; and transmit an instruction related to one or more vehicles associated with the one or more identified principal sources of the airborne pollutant.
A computer implemented method and system for simulating a hydrocarbon reservoir. The method includes determining a computational reservoir model, comprising formation data and fluid pressure data for each of a plurality of reservoir cells, and forming a tridiagonal matrix system for each of M strongly connected lines and arranging arrays of the M tridiagonal matrix systems in a level-based data layout to be stored in a memory of a graphical processing unit (GPU). The method further includes to determining, with the GPU, an unknown potential array for each of the tridiagonal matrix systems by solving the tridiagonal matrix systems simultaneously using a Thomas method configured to operate with the level-based data layout.
A method for determining interfacial tension of a hydrocarbon in a brine fluid, the method including injecting a first brine fluid into a test cell, the first brine fluid having an initial ionic composition, injecting a hydrocarbon fluid into the test cell, contacting the hydrocarbon fluid with the first brine fluid, forming a droplet, measuring the interfacial tension of the hydrocarbon fluid in contact with the first brine fluid, at least partially displacing the first brine fluid with an inert gas, measuring a ionic composition salinity of the displaced first brine fluid in an ionic chromatograph, and comparing the measured ionic composition salinity to the initial ionic composition.
A gas separation membrane, a method for making the gas separation membrane, and a method for using the gas separation membrane are provided. An exemplary gas separation membrane includes a polyether-block-polyamide (PEBA) matrix and a cross-linked network including functionalized polyhedral oligomeric silsesquioxane (POSS) nanoparticles dispersed through the PEBA matrix.
A separator apparatus includes an intake nozzle, first cyclone device, and a second cyclone device. The first and second cyclone devices each include an inlet section, a scroll, a barrel centered on a first axis, a vortex finder, and an underflow portion. The scroll is attached to the inlet section and to the barrel such that the scroll connects the inlet section to the barrel. The vortex finder has a vortex tube arranged concentrically on the axis in an interior volume of barrel. The underflow portion defines an annular gap in fluid connection with the interior volume. The intake nozzle is fluidly connected to the inlet sections of the first and second cyclone devices.
A method for upgrading mixed pyrolysis oil may include contacting the mixed pyrolysis oil with hydrogen in the presence of a mixed metal oxide catalyst at reaction conditions to produce a reaction effluent including light aromatic compounds. The mixed pyrolysis oil includes multi-ring aromatic compounds and is formed from light pyrolysis oil and heavy pyrolysis oil at a ratio of 10:90 to 40:60 with light pyrolysis oil representing a bottom stream of a gas steam cracker and heavy pyrolysis oil representing a bottom stream of a naphtha steam cracker. The mixed metal oxide catalyst includes a plurality of catalyst particles with each catalyst particles including a plurality of metal oxides. An associated system for upgrading mixed pyrolysis oil may include a pyrolysis upgrading unit housing the mixed metal oxide catalyst and a separation unit operable to separate used mixed metal oxide catalyst from the reaction effluent.
B01J 19/24 - Stationary reactors without moving elements inside
B01J 23/00 - Catalysts comprising metals or metal oxides or hydroxides, not provided for in group
B01J 23/83 - Catalysts comprising metals or metal oxides or hydroxides, not provided for in group of the iron group metals or copper combined with metals, oxides or hydroxides provided for in groups with rare earths or actinides
C10G 69/06 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of thermal cracking in the absence of hydrogen
73.
OPTIMIZING HYDROCARBON RECOVERY THROUGH INTEGRATED UTILIZATION OF GEOMECHANICS AND INJECTION/PRODUCTION USING MACHINE LEARNING
Systems and methods include a computer-implemented method for optimized injection/production and placement of wells. Stress change correlations are received over space and time for injection/production of fluids to/from a reservoir. A stress distribution of the reservoir is determined using reservoir geomechanical modeling tools and stress change correlations. Fracture growth/propagation behavior for the reservoir is determined using fracture modeling software and geomechanical properties for optimizing treatment. Fracture design and orientation needed for optimum recovery of hydrocarbons are determined by analyzing relationships between fluid injection/withdrawal and geomechanical changes and stress distribution, reservoir geomechanical, and flow characteristics. Changes in the stress distribution in the reservoir are determined through injection/production of fluids. An optimized injection/production and placement of wells are determined using the changes in the stress distribution and the fracture design and orientation. An optimum stress distribution for placement of new wells is determined using the optimized injection/production and placement of wells.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
A system for upgrading heavy hydrocarbon feeds, such as crude oil, include a hydrotreating unit, a hydrotreated effluent separation system, a solvent-assisted adsorption system, and a hydrocracking unit. Processes for upgrading heavy hydrocarbon feeds include hydrotreating the hydrocarbon feed to produce a hydrotreated effluent that includes asphaltenes, separating the hydrotreated effluent into a lesser boiling hydrotreated effluent and a greater boiling hydrotreated effluent comprising the asphaltenes, combining the greater boiling hydrotreated effluent with a light paraffin solvent to produce a combined stream, adsorbing the asphaltenes from the combined stream to produce an adsorption effluent, and hydrocracking the lesser boiling hydrotreated effluent and at least a portion of the adsorption effluent to produce a hydrocracked effluent with hydrocarbons boiling less than 180° C. The systems and processes increase the hydrocarbon conversion and yield of hydrocarbons boiling less than 180° C.
C10G 67/06 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only including a sorption process as the refining step in the absence of hydrogen
C10G 25/00 - Refining of hydrocarbon oils, in the absence of hydrogen, with solid sorbents
A method of sealing propagating cracks in a sensor-laden cement sheath comprising the steps of monitoring an electrical resistivity of the sensor-laden cement sheath to produce a measured value, wherein the sensor-laden cement sheath comprises a conductive sensor, an on-demand expanding agent, and a cement, activating a heat source when the measured value of the electrical resistivity is greater than an activation threshold, increasing a temperature of the sensor-laden cement sheath with the heat source to an activation temperature, wherein the activation temperature is operable to initiate a reaction between the on-demand expanding agent and water, wherein the activation temperature is greater than a formation temperature, reacting the on-demand expanding agent with water to produce a swelled agent, wherein the swelled agent occupies a greater volume than the on-demand expanding agent, and sealing the propagating cracks in the sensor-laden cement sheath with the swelled agent.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
E21B 47/005 - Monitoring or checking of cementation quality or level
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
E21B 36/04 - Heating, cooling, or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
76.
MODIFIED WHIPSTOCK DESIGN INTEGRATING CLEANOUT AND SETTING MECHANISMS
A system includes a milling assembly with a mill bit and a drill string that mills a new wellbore section. The system further includes a whipstock assembly that is formed by a reamer shoe that reams an obstruction in a wellbore, a whipstock that deflects the milling assembly away from the wellbore, and a bypass valve mechanism that guides a fluid to circulate through the reamer shoe. Within the system, the milling assembly is fluidly connected to the whipstock assembly.
A method includes introducing a drill string including a bottom hole assembly into a wellbore, wherein the bottom hole assembly includes a mounted 3D printing sub-assembly. A wellbore is drilled with the bottom hole assembly, and at least a portion of a casing is printed with the 3D printing sub-assembly while drilling the wellbore. A related system includes a drill string having a length of drill pipe and a bottom hole assembly disposed at a distal end of the length of drill pipe. A 3D printing sub-assembly is mounted on the bottom hole assembly, wherein the printing sub-assembly includes a printer housing and a 3D printing head mounted at the printer housing. A control guides the 3D printing head to print at least a portion of a casing at a location radially away from the central longitudinal axis of the drill string.
A bottom hole assembly (BHA) includes a top sub-assembly configured to couple to a downhole conveyance to move into a wellbore that includes completion components secured in the wellbore; a drill bit configured to drill out and remove a first portion of a subset of the completion components; and an expandable reamer including a cutting assembly and configured to adjust between a retracted position in which a diameter of the cutting assembly is less than a diameter of a bore through at least one of the completion components and an activated position in which the diameter of the cutting assembly is greater than the diameter of the bore. The expandable reamer is further configured to remove a second portion of the subset of the completion components in the activated position.
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 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
A system and method for forming a seismic image of a subterranean region of interest are provided. The method includes obtaining an observed seismic dataset for the subterranean region of interest and determining a plurality of common-offset sections from the observed seismic dataset. The method further includes determining stochastically migrated common-offset sections for each of the common-offset sections and forming a stochastic image gathers from the plurality of stochastically migrated common-offset sections. The method still further includes forming the seismic image by stacking each of the plurality of stochastically migrated common-offset sections.
A method for generating digital emergency alarms is disclosed. The method includes retrieving, by a computing device and from a data packet transmitted by an alarm system controller of a building, an alarm type and an incident location of an emergency incident detected in the building, analyzing, by the computing device based on a building and network layout of at least the building, the alarm type and the incident location to generate an evacuation map specific to a user device connected to the network, where the building and network layout includes a physical location and a network address of the user device, and sending, by the computing device via the network switch based on the network address of the user device, the evacuation map to the user device, where the evacuation map is displayed on the user device to direct a user to evacuate from the emergency incident.
G08B 7/06 - Signalling systems according to more than one of groups ; Personal calling systems according to more than one of groups using electric transmission
G08B 21/02 - Alarms for ensuring the safety of persons
81.
DETERMINING CONCENTRATION OF OIL IN WATER BY EXTRACTION
A method is implemented to determine a concentration of oil in a water sample. A specified amount of cyclohexane is added to the water sample to form a mixture. The mixture is stirred. An oil phase is extracted from the mixture. An absorbance value of the extracted oil phase is measured at a specified wavelength in the visible light spectrum. The specified wavelength is in a range of from 390 nanometers (nm) to 600 nm. The concentration of oil in the water sample is determined based on the measured absorbance value of the extracted oil phase.
G01N 21/31 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry
Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on nuclear magnetic resonance (NMR) spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.
G16C 20/30 - Prediction of properties of chemical compounds, compositions or mixtures
G16C 20/20 - Identification of molecular entities, parts thereof or of chemical compositions
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on simulated distillation (SD) carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself is obtained without fractionation of the oil sample into the several components.
Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on thermogravimetric analysis (TGA) carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.
G01N 5/04 - Analysing materials by weighing, e.g. weighing small particles separated from a gas or liquid by removing a component, e.g. by evaporation, and weighing the remainder
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
85.
METHOD TO PREPARE VIRTUAL ASSAY USING FOURIER TRANSFORM INFRARED SPECTROSCOPY
Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on Fourier transform infrared (FTIR) spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 21/35 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light
Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on fluorescence spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without fractionation of the oil sample into the several components.
A well plugging technique that includes a downhole plug system to be disposed downhole in a well and including a plug bladder system including an inflatable bladder (to be inflated with a resin) and a check valve (to facilitate flow of the resin into, and inhibit back flow of the resin out of, the bladder), and a plug deployment system including a resin chamber to house the resin and a resin deployment system to urge the resin to flow from the resin chamber, through the check valve and into the inflatable bladder while the downhole plug system is disposed downhole in the well, to inflate the plug bladder system into sealing contact with a surrounding downhole portion of the well. The resin including a hardening resin adapted to harden inside of the inflatable bladder to form a hardened plug downhole in the well.
A 3D facies model generator system and methods thereof include a processor and repository comprising (i) facies data, (ii) sequence stratigraphy, and (iii) a depositional model for a subject reservoir. The processor is operable to generate a 3D stratigraphic sequence framework comprising a plurality of facies based on received facies data and sequence stratigraphy, generate a facies volume fraction for each facies, compare each facies volume fraction with the depositional model for the subject reservoir, reassign the facies volume fraction for the facies of the plurality of facies to another facies of the plurality of facies when the comparison determines that the facies of the 3D stratigraphic sequence framework is incorrectly assigned, generate a plurality of 3D probability trends for the plurality of facies based on the facies volume fraction for the respective facies, and generate the 3D facies model based on the 3D probability trends.
A method for well integrity management on a well having at least one surface valve and a surface controlled sub-surface safety valve includes closing the at least one surface valve, applying a predetermined pressure to the at least one surface valve, analyzing a pressure loss across the at least one surface valve, and testing the surface controlled sub-surface safety valve for functionality. Functionality testing of the surface controlled sub-surface safety valve includes opening and closing the surface controlled sub-surface safety valve using a control panel. The method further includes classifying the well as operable or inoperable based on the pressure loss across the at least one surface valve and the functionality of the surface controlled sub-surface safety valve.
Disclosed are methods, systems, and computer-readable medium to perform operations including: calculating a total gas flow rate in a testing trap, where the total gas flow rate includes a first gas flow rate in a liquid leg of the testing trap and a second gas flow rate in a gas leg of the testing trap; calculating a total oil flow rate in the testing trap, where the total oil flow rate includes a first oil flow rate in the liquid leg and a second oil rate in the gas leg; comparing the total gas flow rate and the total oil flow rate to a measured gas flow rate and a measured oil flow rate respectively, where the measured gas flow rate and the measured gas flow rate are measured by a multiphase flow meter; and determining, based on the comparison, whether the multiphase flow meter is calibrated.
A method to improve production of condensate is disclosed. The method includes obtaining a condensate fluids sample from a gas condensate reservoir, generating, from a laboratory pressure, volume and temperature (PVT) experiment of the condensate fluids sample, a liquid dropout curve, performing simulation of the laboratory PVT experiment based on Equations of State (EoS) of the condensate to generate a simulated liquid dropout curve, where the EoS is adjusted to match the simulated liquid dropout curve and the liquid dropout curve generated by the laboratory PVT experiment, performing, based on the adjusted EoS, a reservoir simulation of the gas condensate reservoir under injection of flue gas, where the reservoir simulation models a condensate banking phenomenon to generate an optimal flue gas ratio that maximizes a measure of condensate production, and facilitating, based on the optimal flue gas ratio, the production of the condensate in the gas condensate reservoir.
G01F 1/34 - 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 measuring pressure or differential pressure
G01F 1/74 - Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
G01F 1/84 - Coriolis or gyroscopic mass flowmeters
G01N 9/00 - Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity
G01F 25/10 - Testing or calibration of apparatus for measuring volume, volume flow or liquid level or for metering by volume of flowmeters
93.
METHODS OF RADIATION ACTIVATED LOST CIRCULATION MATERIAL PREVENTION
A system for treating a lost circulation zone within a wellbore that includes a treatment sub 300 is provided. The treatment sub 300 includes a communications device, an internal fluid conduit 1016 configured to convey a wellbore fluid through the treatment sub 100, and the interior 327 of the treatment sub 300 is between a sub exterior surface 328 and the internal fluid conduit 1016. The treatment sub 300 also includes a radiation source 352 configured to generate a form of radiation within a wellbore fluid. Further provided are methods of using the system to treat loss circulation zones.
A computer system obtains a first set of micro-computed tomography (micro-CT) data representing a rock sample obtained from a subterranean formation that includes gas-bearing sandstone. The system obtains a plurality of second sets of micro-CT data in a sequence, each representing the rock sample after a performance of a corresponding triaxial shear test on the rock sample. Performing each triaxial shear test includes applying a triaxial load force to the rock sample, and removing the triaxial load force from the rock sample. The system estimates, based on the first micro-CT data and the plurality of second sets of micro-CT data, one or more characteristics of the underground formation, including a permeability of the underground formation and/or a porosity of the underground formation. The system causes one or more resource extraction operations to be performed on the underground formation based on the one or more characteristics of the underground formation.
G01N 23/046 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and forming images of the material using tomography, e.g. computed tomography [CT]
A smart voltage dip simulator apparatus and method are configured to test a motor starter ride through circuit. The simulator apparatus includes a power supply, an output switch, a test switch, a test lamp, a time selector, and a programmable logic controller. The power supply provides an output voltage to the motor starter when an output switch is actuated. A test of the motor starter is executed and a duration of the test is controlled by a selected time setting. The controller includes code therein configured to apply a predetermined dip to reduce the applied input voltage to the power supply and to generate the output voltage applied to the motor starter for the selected duration of the test. A method is performed to operate the simulator.
Described is a system for detection of microbiologically induced corrosion. The system includes a cathodic protection device configured to generate a signal corresponding to the presence of corrosion near a structure at risk of corrosion. The system also includes an odor sensor configured to generate a signal corresponding to emission of an odor near the structure. Additionally, the system includes a digital circuit connected with the cathodic protection device and the odor sensor. The digital circuit is configured to process the signals from the cathodic protection device and the odor sensor and, based on the processed signals, generate a notification corresponding to presence of microbiologically induced corrosion proximate the structure.
A composition includes an ionic liquid monomer having the following structure:
where n is an integer from 1 to 5 and the ionic liquid monomer has a melting point less than 100° C. A method of making the ionic liquid includes providing a mixture comprising a sulfonic acid and a diamine in a solvent, and maintaining the mixture at a temperature ranging from 10 to 80° C. for a time ranging from 1 to 10 hours to form an ionic liquid monomer having a melting point less than 100° C. A method of making a polymer from the ionic liquid monomer is also provided.
A central tubular defines a central flow passage and spray nozzles along an outer circumference of the central tubular. A first brush pig supports a first end of the central tubular. A second brush pig supports a second end of the tubular. An inflatable balloon is at the second end of the tubular. The inflatable balloon is encircled by the second brush pig. The inflatable balloon is configured to cause a first pressure drop across the balloon when in an inflated state and cause a second pressure drop, less than the first pressure drop, across the balloon when in a deflated state. A flow control system is at the first end of the tubular and is configured to regulate fluid exchange with the tubular and fluid exchange with the inflatable balloon.
B05C 7/08 - Apparatus specially designed for applying liquid or other fluent material to the inside of hollow work by devices moving in contact with the work for applying liquids or other fluent materials to the inside of tubes
C23F 11/00 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
B05C 7/02 - Apparatus specially designed for applying liquid or other fluent material to the inside of hollow work the liquid or other fluent material being projected
B05D 7/22 - Processes, other than flocking, specially adapted for applying liquids or other fluent materials to particular surfaces or for applying particular liquids or other fluent materials to internal surfaces, e.g. of tubes
A drag reducing efficiency test is performed on a sample. The sample includes a crude-oil based fluid and a drag reducing agent. The sample is placed within an inner volume defined by a sample housing. A sensing portion of a sensor is submerged in the sample within the sample housing. The sensor includes a disk (sensing portion) and a supporting rod. A lid is placed on the sample housing to isolate the sample within the inner volume. The sensor is coupled to an air bearing motor. The sensor is rotated by the air bearing motor at a plurality of shear rates. For each shear rate, the sensor measures a torque applied by the sample on the disk in response to the disk rotating while submerged in the respective sample at the respective shear rate.
G01N 11/14 - Investigating flow properties of materials, e.g. viscosity or plasticity; Analysing materials by determining flow properties by moving a body within the material by using rotary bodies, e.g. vane
100.
METHOD TO PREPARE VIRTUAL ASSAY USING NEAR INFRARED SPECTROSCOPY
Systems and methods are disclosed for providing virtual assays of an oil sample such as crude oil based on near infrared (NIR) spectroscopy carried out on the oil sample, and the density of the oil sample. The virtual assay provides a full range of information about fractions of the oil sample including naphtha, gas oil, vacuum gas oil, vacuum residue, and other information about the properties of the oil sample. Using the system and method herein, the virtual assay data pertaining to these several fractions of the oil sample and the oil sample itself are obtained without the need to fractionate the oil sample into the several components.
G01N 11/00 - Investigating flow properties of materials, e.g. viscosity or plasticity; Analysing materials by determining flow properties
G01N 21/359 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light using near infrared light
G01N 21/3577 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing liquids, e.g. polluted water
