A system and a method for removing gas field chemicals from a feed stream are provided. An exemplary method includes performing a forward osmosis on a feed stream including gas field chemicals to form a concentrated feed stream, and treating the concentrated feed stream in an electrochemical process to form treated water.
C02F 9/00 - Multistage treatment of water, waste water or sewage
B01D 61/00 - Processes of separation using semi-permeable membranes, e.g. dialysis, osmosis or ultrafiltration; Apparatus, accessories or auxiliary operations specially adapted therefor
C02F 1/00 - Treatment of water, waste water, or sewage
C10G 33/00 - De-watering or demulsification of hydrocarbon oils
2.
VALIDATION AND OPTIMIZATION OF INDUSTRIAL CARBON FOOTPRINT EMISSIONS REDUCTION
Systems and methods include a method for generating optimum de-carbonization investment plans. An optimization objective is determined for reducing carbon dioxide (CO2) emissions of an organization. A CO2 emissions baseline for the organization is determined. An optimum de-carbonization investment plan is generated for the organization using the optimization objective and the CO2 emissions baseline for the organization. The optimum de-carbonization investment plan is configured to minimize life cycle costs of the organization while meeting emission reduction targets of the organization.
A method includes drilling a wellbore into a subsurface using a drill bit and, for each of a plurality of depths of the drill bit in the wellbore, detecting, at each of a plurality of receiver stations located along a fiber optic cable disposed behind a casing string within the wellbore, a seismic signal created by the drill bit drilling the wellbore, sending an optical signal generated by the detection of the seismic signal from each of the plurality of receiver stations to an interrogator, sorting, using a computer processor, the optical signals by receiver station, and determining, using the computer processor, a seismic velocity using first breaks picked from the sorted optical signals.
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 49/00 - 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
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
4.
TWO STAGE CATALYTIC PROCESS FOR MIXED PYROLYSIS OIL UPGRADING TO BTEX
In accordance with one or more embodiments of the present disclosure, a multi-stage process for upgrading a mixed pyrolysis oil comprising polyaromatic compounds to benzene, toluene, ethylbenzene, and xylenes (BTEX) includes combining light pyrolysis oil with heavy pyrolysis oil to form the mixed pyrolysis oil; upgrading the mixed pyrolysis oil in a slurry-phase reactor zone to produce intermediate products, wherein the slurry-phase reactor zone comprises a mixed metal oxide catalyst; and hydrocracking the intermediate products in a fixed-bed reactor zone to produce the BTEX, wherein the fixed-bed reactor zone comprises a mesoporous zeolite-supported metal catalyst.
C10G 69/04 - 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 catalytic cracking in the absence of hydrogen
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
B01J 29/04 - Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites, pillared clays
C10G 11/14 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
C10G 45/68 - Aromatisation of hydrocarbon oil fractions
C10G 47/20 - Crystalline alumino-silicate carriers the catalyst containing other metals or compounds thereof
5.
METHOD AND SYSTEM FOR DETERMINING WAVEFIELD COMPONENTS USING INDEPENDENT COMPONENT ANALYSIS
A method may include determining various migrated azimuthal dip-angle gathers based on a migration function and seismic data from a seismic survey regarding a geological region of interest. The method may further include determining various partial dip-angle images using the migrated azimuthal dip-angle gathers. The method may further include determining various azimuthal bins that include the partial dip-angle images. The method may further include determining various wavefield components using an independent component analysis (ICA) function and the partial dip-angle images among the azimuthal bins. The method may further include determining a geological feature within the geological region of interest using the wavefield components.
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
A well system includes a wellbore penetrating a subterranean formation, production tubing extended into the wellbore and terminating at a completion string, and one or more inflow control devices forming part of the completion string. The inflow control device includes a base pipe defining one or more first flow ports and one or more second flow ports axially spaced from the first flow ports. A first flow regulation device is arranged within the base pipe and actuatable to expose or occlude the first flow ports, and a second flow regulation device is arranged within the base pipe and actuatable to expose or occlude the second flow ports. A downhole shifting device is operable to independently manipulate a position of the first and second flow regulation devices and thereby selectively expose or occlude the first or second flow ports.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A process for reducing the interfacial tension between a hydrocarbon fluid and a surfactant mixture during chemical enhanced oil recovery includes introducing a surfactant mixture solution comprising an anionic surfactant, a cationic surfactant, a nonionic surfactant, a brine solution, and a co-solvent to a hydrocarbon-bearing reservoir under conditions of a salinity of greater than or equal to 50,000 mg/L, a hardness of greater than or equal to 2,500 mg/L, and a temperature of greater than or equal to 90° C., thereby reducing the interfacial tension at a liquid-liquid interface of the hydrocarbon fluid and the surfactant mixture solution. The anionic surfactant comprises organo sulfate. The cationic surfactant comprises quaternary ammonium, brominated trimethylammonium, chloride trimethylammonium, or combinations thereof. The nonionic surfactant comprises polyoxyethylene fatty acid ester, phenylated ethoxylate, or combinations thereof.
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
A system includes an electric submersible pump and a flow regulating valve. The electrical submersible pump includes a pump that, when activated, receives a fluid disposed within a production tubing of a well through a pump intake and vents the fluid through a pump discharge to a surface location. The flow regulating valve includes a flow tube that blocks the fluid from entering the pump intake when the pump is inactive, a piston, connected to the flow tube, that moves the flow tube within the flow regulating valve, and a stinger that includes a conduit for the fluid to flow from the production tubing to the pump. The flow regulating valve further includes a spring that positions the piston within the flow regulating valve when the pump is inactive and a plurality of seals that pressure-seal a pressure chamber which houses a pressure force that is to be applied upon the piston.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A system includes a tubing head, a bushing profile, and a wear bushing. The tubing head is connected to the casing head. The bushing profile is formed by a tubing head inner surface of the tubing head. The wear bushing has a bushing external surface configured to mate with the bushing profile. An orifice is formed by the installation of the wear bushing in the bushing profile and the connection between the tubing head and the casing head
A process of producing a mesoporous beta zeolite includes mixing a crystalline beta zeolite with one or more solvents, cetyltrimethylammonium bromide, and metal hydroxide to produce a solution, heating the solution at a temperature of from 50° C. to 150° C. to convert the crystalline beta zeolite to a non-crystalline material with reduced silica content relative to the crystalline beta zeolite, cooling the solution to a temperature of from 25° C. to 40° C., adjusting the pH of the solution to from 8 to 10 by adding an acid, and aging the solution at a temperature of from 50° C. to 150° C. for a time period sufficient to crystalize the non-crystalline material to produce beta zeolite particles.
C01B 39/46 - Other types characterised by their X-ray diffraction pattern and their defined composition
B01J 29/70 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of types characterised by their specific structure not provided for in groups
C10G 47/02 - Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, to obtain lower boiling fractions characterised by the catalyst used
C10G 47/30 - Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, to obtain lower boiling fractions with moving solid particles according to the "fluidised bed" technique
An untethered downhole tool includes a first body, a second body, a logging sensor, a motor, and a controller. Each of the first and second bodies includes a housing that defines an inner volume and a magnetic anchor configured, in an active state, to attach the body to a wellbore tubular. The motor is attached to one of the first or second bodies and coupled to a spooler. The controller is communicably coupled to the motor and the first and second magnetic anchors. The controller is configured to adjust one of the first or second magnetic anchors from the active state to an inactive state; and activate the motor to operate the spooler to spool the cable from the spooler to increase a length of a portion of the cable between the spooler and the detached first or second body.
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 47/26 - Storing data down-hole, e.g. in a memory or on a record carrier
A system includes an electric submersible pump assembly and a control valve assembly. The electric submersible pump assembly transports a fluid in a casing string of a well to a surface location and includes a pump that receives the fluid through a pump intake and vents the fluid through a pump discharge when activated. The electric submersible pump assembly further includes a shaft that is fixed to the pump and extends downhole from the pump. The control valve assembly includes a propeller shaft axially movable along a central axis of the system, a propeller attached to the propeller shaft that pushes the propeller shaft downhole when the pump of the electric submersible pump assembly is active, a shaft coupler that connects the propeller shaft and the shaft of the electric submersible pump assembly, and a stinger that has a conduit for the fluid to flow from the casing string to the pump intake. The stinger includes an entrance for receiving the fluid and an exit for venting the fluid to the pump intake of the electric submersible pump assembly. In addition, the control valve assembly includes a flow tube, connected to the propeller shaft, and a spring. The flow tube includes ports which create fluid communication between the flow tube and the stinger when the ports and the entrance of the stinger are aligned. The spring slides the propeller shaft when the pump of the electric submersible pump assembly is inactive.
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
E21B 43/34 - Arrangements for separating materials produced by the well
A system includes an electric submersible pump (ESP) assembly configured to transport a fluid in a casing string of a well to a surface location. The ESP includes a pump configured to receive, upon activation, the fluid through a pump intake and vent the fluid through a pump discharge; an output shaft extending downhole from and fixed to the pump; and a control valve assembly. The control valve assembly includes a movable core of an electromagnet movable along a central axis of the system; a generator attached to the electromagnet, configured to generate electrical power to pull the movable core in an uphole direction upon activation of the pump of the electric submersible pump assembly; a shaft coupler coupling a generator input shaft and the output shaft; and a stinger having a conduit for the fluid to flow from the casing string to the pump intake. The stinger includes at least one intake slot configured to receive the fluid; and an exit configured to vent the fluid to the pump intake of the electric submersible pump assembly. The control valve assembly also includes a flow tube connected to the movable core, the flow tube comprising an exterior surface creating fluid communication between the flow tube and the stinger before, when, or after the exterior surface uncovers the at least one intake slot of the stinger. The ESP also includes a spring configured to slide the movable core upon deactivation of the pump of the electric submersible pump assembly.
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
Inventor
Al-Harbi, Bader Ghazi
Saleh, Tawfik A.
Aljeaban, Norah A.
Abstract
A method includes preparing an alkyl-modified graphene oxide, injecting the modified graphene oxide into a well, and inhibiting acid-induced corrosion of a steel surface in the well with the modified graphene oxide. A composition includes an alkyl-modified graphene oxide having one or more alkyl functional group covalently bonded to a graphene core through an oxygen-containing linking group. A method of preparing modified graphene oxide includes mixing graphite powder with an oxidant to provide a mixture, adding the mixture to an acid solution including H2SO4, H3PO4, or a combination thereof to provide graphene oxide, and reacting the graphene oxide with an alkyl halide by nucleophilic substitution to provide the alkyl-modified graphene oxide.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
15.
LANTHANIDE-DOPED MATERIALS FOR THE DESIGN AND FABRICATION OF PV SOLAR PANELS WITH IMPROVED ENERGY EFFICIENCY
A layered photovoltaic device and a composition for a topcoat of a photovoltaic device are described. The layers of the photovoltaic device include a topcoat and a silicon cell. The topcoat includes one or more first nanoparticles and a polymer. The first nanoparticles comprise a lattice material and two or more Lanthanide ions. The topcoat composition comprises a polymer and one or more first nanoparticles dispersed within the polymer. The one or more nanoparticles comprise a lattice including a first material comprising ytterbium.
H01L 31/0352 - SEMICONDUCTOR DEVICES NOT COVERED BY CLASS - Details thereof characterised by their semiconductor bodies characterised by their shape or by the shapes, relative sizes or disposition of the semiconductor regions
16.
MACHINE LEARNING-BASED TIMESTEP SELECTION FOR ITERATIVE NUMERICAL SOLVERS
A method for accelerating numerical solution of a differential equation representing fluid flow in porous media associated with hydrocarbon well environments involves obtaining input data associated with a previous timestep of a numerical solver operating on the differential equation, predicting, by a machine learning model, a current timestep size for the numerical solver from the previous timestep to a current timestep immediately following the previous timestep, and executing the numerical solver using the current timestep size on the differential equation to generate a simulation output for the current timestep.
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
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
A combined chemical injection and mixing system including an injection stream pipe, a target pipe disposed within the injection stream pipe, and a plurality of injection quills is described. The injection stream pipe encloses the plurality of injection quills, and the plurality of injection quills each independently includes a quill check valve and a quill flange. A method for mixing at least one chemical in a pipeline is also described. The method includes providing a chemical injection and mixing system configured to a pipeline, forming a pipeline treatment system, providing a fluid flow in the pipeline treatment system, injecting at least one chemical via the plurality of injection quills, and mixing the at least one injected chemical in a mixing zone of the chemical injection and mixing system, thereby mixing the at least one injected chemical in the fluid flow.
In some examples, a method can include determining a number of mobile stations that have been used by users to implement a call during a period of time using a base station of a telecommunications network based on traffic data, and determining that the number of mobile stations is equal to or within a value or range of a base station support threshold for the base station, which indicates that there is a probability that a given mobile station of mobile stations will be blocked or denied access from initiating a respective call in using the base station. The method further can include determining a number of additional channels that are needed for the base station to reduce the probability that the given mobile station of the mobile stations will be blocked or denied access from initiating the respective call in the future using the base station.
A system and method perform automated detection, classification, and remediation of defects in a structure using ultrasound testing. The system includes an autoencoder is trained and configured to generate a de-noised UT scan image from a noisy UT scan image of a structure, a support vector machine configured to detect a defect in the structure, a convolutional neural network configured to classify the defect, and a remediation subsystem configured to remediate the defect. The method implements the system.
A method and a system for tracking a concentration of pollution elements in air are disclosed. The system includes a plurality of air pollutant monitoring stations configured to obtain data from a plurality of air samples and an information logger that communicates with the plurality of the air pollutant monitoring stations and that is configured to collect and organize the data obtained from the plurality of the air pollutant monitoring stations in the real time or periodically. Further, a data storage is engaged with the information logger and stores the collected data into a relational database, creates triggers for instances when air pollution parameters exceed a given limit value, and triggers an alert. Additionally, a geographic information system analyzes the stored data, geo-locates the plurality of the air pollutant monitoring stations and the analyzed data, and generates reports based on the analysis of the stored data
A downhole vibration tool includes a head unit, a housing, a power system, a control system, at least one electrical motor, an engagement system, at least one vibration module, and at least one tractor section. The head unit is configured to attach to a conveyance system in a wellbore. The housing is configured to receive the cable head and house the power system, the control system, the at least one electrical motor, the engagement system, the vibration module and the at least one tractor section. The engagement system is configured to extend outward from the housing and contact the wellbore.
E21B 31/00 - Fishing for or freeing objects in boreholes or wells
E21B 47/18 - 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 using acoustic waves through the well fluid
22.
DUAL DETACHED WIPER PLUG SYSTEM FOR CEMENTING OPERATION
A cementing string assembly for cementing a liner in a wellbore includes a drill pipe, a liner hanger running tool attached to the drill pipe, a liner releasably secured to the liner hanger running tool, an upper wiper plug disposed within the liner and releasably secured to the liner hanger running tool or to the liner, and a lower wiper plug disposed within the liner and releasably secured to the liner downhole of the upper wiper plug. The lower wiper plug is detached from the upper wiper plug. The lower wiper plug is releasably secured to an inner surface of the liner by a wiper plug hanging collar and is releasable from the liner independent of the upper wiper plug and without exerting forces on the upper wiper plug. The cementing string assembly prevent premature and unintentional release of the upper wiper plug while releasing the lower wiper plug.
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A system for securely transmitting data includes a data network that connects to an internet network using an internet protocol. The system also includes a user equipment (UE) that transmits a request to access enterprise data, and a base station that receives and forwards the access request to an enterprise platform. The enterprise platform includes a Multi-access Edge Computing (MEC) server that receives and forwards the access request to an enterprise server that accesses a data center storing the enterprise data. Within the enterprise platform, a first security module receives the access request from the base station, determines that an access request is secure, and forwards secure access requests to the MEC server through an encrypted connection. The MEC server transmits the processed data through the first security module to the base station and the UE, which are connected to the internet network with the first security module.
A method may include receiving a core description comprising a plurality of lithofacies and at least one sequence boundary, generating a depositional ordering model of the plurality of lithofacies from the core description, and using the depositional ordering model to construct a 2D depositional model of a horizontal arrangement of the plurality of lithofacies.
G01V 99/00 - Subject matter not provided for in other groups of this subclass
E21B 49/02 - 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 by mechanically taking samples of the soil
Systems and methods include a method for determining the purity of a sample. An image capture is performed of a reference material having a known purity and an unknown material having an unknown purity for which a priori information is known, including that the reference material and the unknown material have a same material type. An image comparison of the reference material and the unknown material is performed to determine a color difference vector between an image of the reference material and an image of the unknown material. A purity of the unknown material is determined using the color difference vector.
A well site includes a wellbore extending from a surface to a target reservoir. A production tubing extends into the wellbore from the surface. The production tubing forms a flow conduit from the target reservoir to the surface. A pump is coupled to the production tubing to lift well fluids to the surface. A sand level device is coupled below the pump. The level device includes one or more transmitters to generate and transmit at least two signals down the wellbore and one or more receivers to receive the at least two signals reflected from a surface in the wellbore. A time duration of transmitting and receiving the at least two signals may correspond to a straight-line distance between the sand level device and the surface in the wellbore. The sand level device is configured to send an alarm when the straight-line distance does not suppress a predetermined threshold.
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
27.
Treatment system for gasoline compression ignition engine exhaust
A system for treatment of gasoline compression ignition engine exhaust includes components of a carbon monoxide absorber and a nitrogen oxide absorber, wherein nitrogen oxide comprises one or more compounds consisting of nitrogen and oxygen; an oxidation catalyst downstream of the carbon monoxide absorber; a close coupled reduction catalyst downstream of the nitrogen oxide absorber; an underfloor reduction catalyst downstream of the close coupled reduction catalyst; and an ammonia slip catalyst downstream of the underfloor reduction catalyst. A method for making the system includes aligning the components into the system; configuring the carbon monoxide absorber to capture and store carbon monoxide under cold start operation; configuring the nitrogen oxide absorber to capture and store nitrogen oxide, under cold start operation; and configuring the underfloor reduction catalyst and ammonia slip catalyst to in combination reduce slip ammonia released by the close coupled reduction catalyst under high load operation.
F01N 3/20 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous by thermal or catalytic conversion of noxious components of exhaust characterised by methods of operation; Control specially adapted for catalytic conversion
F01N 3/10 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous by thermal or catalytic conversion of noxious components of exhaust
A method of operating an engine includes operating the engine in first and second engine operating map regions by performing passive jet ignition combustion with a first stoichiometric fuel mixture and a first volume of residual gas. The engine is operated in a third engine operating map region by performing turbulent jet controlled compression ignition (TJCCI) with an ultra lean fuel mixture and a first volume of cooled exhaust gas recirculation, a fourth engine operating map region by performing passive jet ignition combustion with a third stoichiometric fuel mixture and a second volume of cooled exhaust gas recirculation, and a fifth engine operating map region, characterized by shutting off the engine. The engine is operated in a mode transition region between the second, third, and fourth engine operating map regions by performing passive jet ignition combustion with a second stoichiometric fuel mixture and a second volume of residual gas.
F02P 5/04 - Advancing or retarding electric ignition spark; Control therefor automatically, as a function of the working conditions of the engine or vehicle or of the atmospheric conditions
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
Inventor
Kalgaonkar, Rajendra Arunkumar
Bataweel, Mohammed Abudullah
Baqader, Nour Othman
Ullah, Nisar
Mansha, Muhammad
Abstract
A diverter agent includes a morpholinium based zwitterionic surfactant having a sulfonate terminal moiety; and an ammonium based zwitterionic surfactant.
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
30.
REMOTE FIELD EDDY CURRENT BASED SYSTEM AND METHOD FOR CORROSION INSPECTION
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
SAUDI ARABIAN OIL COMPANY (Saudi Arabia)
Inventor
Ahmed, Shehab
Bagci, Hakan
Khater, Moutazbellah A.
Larbi Zeghlache, Mohamed
Mostafa, Tarek Mahmoud Atia
Ooi, Guang An
Ozakin, Mehmet Burak
Abstract
A remote field eddy current, RFEC, system for detecting an azimuth location of a defect in a pipe includes a holder extending along a longitudinal axis X and shaped to flow through the pipe, a magnetic field generator located within the holder and configured to generate a first magnetic field B0, a 3-axis fluxgate magnetometer located within the holder, at a given distance away from the transmitter, along the longitudinal axis X, wherein the fluxgate magnetometer is configured to measure a second magnetic field B, which is a result of the first magnetic field B0 interacting with the defect in the pipe, and a controller located within the holder and configured to receive a value of the second magnetic field B and to determine an azimuth of the defect in the pipe by interpreting radial components of the measured field, and an extent of the defect based on the second magnetic field B.
G01N 27/90 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables for investigating the presence of flaws using eddy currents
31.
METHOD OF PRODUCING A FUEL OIL INCLUDING PYROLYSIS PRODUCTS GENERATED FROM MIXED WASTE PLASTICS
Method of producing a fuel oil comprising pyrolysis products from waste plastics includes conducting pyrolysis of a plastic feedstock to produce plastic pyrolysis oil; feeding the plastic pyrolysis oil to a first fractionator to separate the plastic pyrolysis oil into a distillate fraction and a topped pyrolysis product fraction split at a boiling point in the range of 80° C. to 250° C.; and feeding the topped pyrolysis product fraction along with other hydrocarbon streams to a fuel oil blending unit to generate a fuel oil product stream. An associated system for preparing a fuel oil comprising pyrolysis products from waste plastics is also provided.
C10L 1/04 - Liquid carbonaceous fuels essentially based on blends of hydrocarbons
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 1/02 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by distillation
C10G 1/10 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal from rubber or rubber waste
A method and system for determining a mass of an absorbed gas and a mass of a pore gas in a sample using NMR spectroscopy is provided. The method includes acquiring a baseline NMR spectrum of a pressure cell containing the sample, saturating the sample with a gas, acquiring a saturated NMR spectrum and determining a differential NMR spectrum of the sample by subtracting the baseline NMR spectrum from the saturated NMR spectrum. The method also includes separating the differential NMR spectrum into an absorbed gas NMR spectrum to determine an absorbed gas NMR signal and a pore gas NMR spectrum to determine a pore gas NMR signal by performing a spectral deconvolution. The method further includes acquiring a normalization NMR spectrum of the pressure cell containing a gas to determine a gas calibration NMR signal and determining the mass of the absorbed gas and pore gas.
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
A downhole tubing disconnect assembly includes a first tubing portion disposed in a wellbore, a second tubing portion downhole of the first tubing portion, and an actuation sleeve positioned between the first tubing portion and the second tubing portion. The actuation sleeve has a cylindrical body that selectively connects the first tubing portion and the second tubing portion. The actuation sleeve includes an uphole portion of the cylindrical body to selectively engage the first tubing portion, a downhole portion of the cylindrical body to selectively engage the second tubing portion, and a shifting profile in the cylindrical body. The shifting profile selectively engages a shifting tool disposed within the wellbore.
Systems and methods include techniques for using smart polymers. Units of smart polymers with chloride ion sensitivity are inserted into drilling fluid pumped into a well. The smart polymers are configured to be triggered by chlorine ion concentrations. An insertion timestamp associated with each unit is stored. Each insertion timestamp indicates a time that each unit was inserted. Continuous images and observed characteristics of returning mud exiting through an annulus of the well and containing the units of smart polymers are captured by a camera positioned at a sensing location and linked to the monitoring system. An estimate of salinity in the drilling fluid is determined using continuous images, observed characteristics, and insertion timestamps, and based at least in part on executing image processing algorithms, machine-learning models, and deep-learning models. Changes to drilling parameters are suggested based on the estimate of the salinity.
G01N 21/78 - Systems in which material is subjected to a chemical reaction, the progress or the result of the reaction being investigated by observing the effect on a chemical indicator producing a change of colour
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
A composition comprising a promotor component is disclosed comprising a mixture of one or more catalytically active components and one or more oxidized disulfide oil (ODSO) compounds, including a water-soluble fraction of ODSO. A composition comprising an aqueous solution of one or more catalytically active components and a promotor component is also disclosed. In certain embodiments the ODSO is obtained from the effluent of an enhanced MEROX process. The compositions facilitate transfer of catalytically active components (or components that will be catalytically active in the finished solid catalyst material) onto the surface of support materials.
A tubular joint for a well string includes an elongated tube that includes an inner surface and an outer surface; a thrusting element affixed to the inner surface of the tubular joint; and a landing pad disposed along the tubular joint, the landing pad secured to the thrusting element by a spring. The landing pad is configured to move outward from the outer surface relative to the thrusting element.
Systems and methods include techniques for using smart polymers. Units of smart polymers with hydrogen sulfide (H2S) sensitivity are inserted by a monitoring system into drilling fluid pumped into a well. The smart polymers are configured to be triggered by increasing H2S concentrations. An insertion timestamp associated with each unit is stored. Each insertion timestamp indicates a time that each unit was inserted. Continuous images and observed characteristics of returning mud exiting through an annulus of the well and containing the units of smart polymer are captured by a camera positioned at a sensing location and linked to the monitoring system. An estimate of H2S levels at a drill bit of the drilling operation is determined using continuous images, observed characteristics, and insertion timestamps, and based at least in part on executing image processing algorithms, machine-learning models, and deep-learning models. Changes to drilling parameters are suggested.
Systems and methods include techniques for using smart polymers. Units of smart polymers with heat sensitivity are inserted by a monitoring system into drilling fluid pumped into a well. The smart polymers are configured to be triggered by exposure to increasing levels of heat. An insertion timestamp associated with each unit is stored. Each insertion timestamp indicates a time that each unit was inserted. Continuous images and observed characteristics of returning mud exiting through an annulus of the well and containing the units of smart polymer are captured by a camera positioned at a sensing location and linked to the monitoring system. An estimate of temperatures at a drill bit of the drilling operation is determined using continuous images, observed characteristics, and insertion timestamps, based at least in part on executing image processing algorithms, machine-learning models, and deep-learning models. Suggested changes to be made to drilling parameters are provided.
A system and method for providing real-time predictive carbon dioxide (CO2) corrosion rate modelling for an oil and gas operation facility includes a modeling system configured to receive dynamic process input data of the oil and gas operation facility, including data relating to CO2 inhibitor residuals of the oil and gas operation facility. The modeling system implements a semi-empirical real-time corrosion rate model and an injection control module operable to control an injection rate of CO2 inhibitor into a component of the oil and gas operation facility based on the semi-empirical real-time corrosion rate model.
A method to assess reservoir continuity between single wells in an oilfield formation within a region with several petroleum reservoirs, including the steps: collecting water samples from each of the single wells, obtaining the geochemical composition of each of the water samples, obtaining a dataset from the geochemical compositions of the single wells, analyzing the dataset using principal component analysis to obtain principal components of the dataset, clustering the principal components to obtain clusters, identifying hydrodynamic groups from the clusters, assigning the wells to hydrodynamic groups, wherein wells within one single hydrodynamic group are considered to be hydraulically communicated.
Systems and methods are disclosed. The method includes obtaining a first seismic dataset generated by a passive seismic source at a first epoch for an inter-wellbore region of interest lying between a first wellbore and a second wellbore. The first seismic dataset includes a first plurality of seismic traces recorded by a first optical fiber in the first wellbore and a second plurality of seismic traces recorded by a second optical fiber in the second wellbore. The method further includes determining a first virtual seismic dataset by applying seismic interferometry to the first seismic dataset. The method still further includes determining a first seismic velocity model for the inter-wellbore region of interest by applying seismic inversion to the first virtual seismic dataset.
Systems and methods for automated first arrival picking are disclosed. The method includes obtaining a seismic dataset composed of a plurality of seismic gathers and determining a pilot for each gather, where the pilot includes a position on an ordinate axis for each seismic trace representing a first arrival. The method continues iteratively until a stopping criterion is met by creating a preconditioned gather using the pilot, determining a differential pilot using global path tracing subject to a constraint and incrementing the pilot using the differential pilot to create a total picked first arrival. Once the stopping criterion has been met, the method further includes determining a final picked first arrival based on the total picked first arrival, determining a seismic velocity model from the final picked first arrival using a tomographic inversion and creating a seismic image using the seismic velocity model and the seismic dataset.
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 47/0224 - Determining slope or direction of the borehole, e.g. using geomagnetism using seismic or acoustic means
A cement bond test cell includes an outer cylinder and an inner cylinder coaxially disposed within the outer cylinder along a central axis. The inner cylinder defines an inner volume configured to be filled with a fluid. An annulus is formed between the outer cylinder and the inner cylinder and configured to be filled with a test cement. The cement bond test cell further includes an acoustic transmitter disposed within the inner volume and configured to be acoustically coupled to an interior surface of the inner cylinder by the fluid. The cement bond test cell further includes at least one acoustic receiver acoustically coupled to an exterior surface of the outer cylinder.
G01N 3/24 - Investigating strength properties of solid materials by application of mechanical stress by applying steady shearing forces
G01N 29/07 - Analysing solids by measuring propagation velocity or propagation time of acoustic waves
G01N 29/14 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object using acoustic emission techniques
The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for determining carbon environmental impact for oil and gas pipeline leakages. One computer-implemented method includes: determining, by one or more hardware processors, an amount of Equivalent Carbon Dioxide (ECO2) associated with a pipeline leak in a hydrocarbon reservoir; determining, by one or more hardware processors, a probability of failure of the pipeline leak in the hydrocarbon reservoir; determining, by one or more hardware processors, an environmental consequence factor of the pipeline leak in the hydrocarbon reservoir; determining, by one or more hardware processors, a severity factor of the pipeline leak in the hydrocarbon reservoir based on at least one of the amount of ECO2, the probability of failure, or the environmental consequence factor; and outputting, by one or more hardware processors, the severity factor in a user interface.
A system for producing hydrocarbons from a subsurface formation includes a main wellbore, a first lateral extending off the main wellbore, the first lateral configured to produce hydrocarbons from the subsurface formation to a ground surface through the main wellbore, a second lateral extending off the main wellbore, tubing extending down the main wellbore into the second lateral, and a tool attached to the tubing. The tool includes a support structure with a longitudinal axis and having a cylindrical shape, the support structure including one or more latching mechanisms, expandable packers mechanically coupled to the support structure, the expandable packers being radially expandable to secure the tool within the second lateral, an electromagnetic source mechanically coupled to the support structure and operable to generate electromagnetic radiation, and an antenna communicatively coupled to the electromagnetic source and operable to transmit the electromagnetic radiation, the antenna being at least partially disposed within the expandable casing.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
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
46.
REAL-TIME MEASUREMENTS OF PHYSICAL PROPERTIES OF DRILLED ROCK FORMATIONS DURING DRILLING OPERATIONS
Systems and methods include a method for determining drilling information. A cutting concentration in annulus (CCA) is determined while drilling a well using drilling parameters and mud properties. An effective mud weight of mud and an equivalent circulating density (ECD) of mud used in the well are determined. A bulk formation rock density (RHOB) of cuttings from the well is estimated using the ECD, a bulk density model, and a bulk density log, where the cuttings are produced by drilling the well through rock formations. A fluid formation density (RHOF) and a mud matrix formation rock density (RHOM) for the well are estimated. A porosity of geological structures through which the well is drilled and a formation resistivity factor (FR) of formations are estimated. A velocity of wave propagation of waves through the formations is evaluated. An ultimate compressive strength (UCS) is estimated for the well.
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 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
47.
ADVANCED FLOW RATE MEASUREMENT USING CHEMICAL PROSPECTOR OF OIL AND GAS PRODUCERS
A system for identifying and quantifying a fluid in a gas-oil separation plant conduit includes a first wellhead and a second wellhead, a first flowline, a first prospector spool apparatus and a second prospector spool apparatus, a header, and a collection point. The first and the second prospector spool apparatus each include a porous layer with a prospector molecule. The prospector molecule has chemical affinity for oil, gas, or water, and is configured to diffuse into fluid flow. A method includes providing a system, producing a first fluid from a first well and a second fluid from a second well, flowing the first fluid through the first prospector spool apparatus and the second fluid through the second prospector spool apparatus, allowing the first fluid and the second fluid to commingle, collecting a sample of and analyzing the commingled fluid to provide a quantitative and qualitative analysis.
A wireline fishing tool includes a body having opposing upper and lower ends and defining an inner flowpath extending between the upper and lower ends, a spear arranged within the inner flowpath and including a spear body having opposing uphole and downhole ends and an inner channel extending between the uphole and downhole ends. One or more hooks are pivotably attached to the spear body at the downhole end, wherein the spear is movable between a retracted state, where the one or more hooks are arranged within the inner flowpath, and an extended state, where the spear body extends out of the inner flowpath at the lower end and the one or more hooks exiting the inner flowpath, and the one or more hooks pivot radially outward and away from the spear body upon exiting the inner flowpath.
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
A system for removing contaminants from a tubular pipe. The system may include a wiper plug with a plurality of wipers. The wipers may include a first wiper with a first diameter different from a second diameter of a second wiper. The system may include a landing profile that may include at least two arms configured to extend outward. The system may include a valve disposed in an internal bore of the wiper plug. The valve may include a plurality of shear pins configured to hold the valve in a closed position and to break from increasing pressure to allow the valve to open. The system may include a nipple comprising a latch profile configured to cooperate with the landing profile of the wiper plug for holding the wiper plug in the tubular pipe.
A method to perform a pressurized test of a pressure retaining equipment is disclosed. The method includes inserting, via a nozzle of the pressure retaining equipment, a waterproof wireless sensor assembly into an enclosed volume of the pressure retaining equipment, closing, subsequent to said inserting, all openings of the pressure retaining equipment except a connection to a pump, applying, by the pump, pressure to a test fluid contained in the enclosed volume, wirelessly transmitting, by the wireless sensor assembly to a computing device external to the pressure retaining equipment, test readings, and analyzing, by the computing device, the test readings to determine a result of the pressurized test.
The present disclosure relates to methods for preparing a poly(crown ether). The present disclosure also relates to poly(crown ether)s prepared according to such methods.
A system and method for removing sulfur compounds from gas, including discharging tail gas having sulfur compounds from a sulfur recovery unit (SRU) to a non-thermal plasma (NTP) catalytic unit including an NTP reactor, providing oxidant to the NTP reactor and placing the oxidant in an NTP state in the NTP reactor to give an oxidative reactive species formed from the oxidant, converting (oxidizing) the sulfur compounds with the oxidative reactive species and catalyst in the NTP catalytic unit into sulfur oxides (SOx) to discharge the tail gas as treated having the formed SOx without the sulfur compounds that were converted. The SOx is absorbed into water in a quench tower to give the tail gas beneficially having only small amounts (e.g., less than 200 ppmv) of sulfur compounds. SOx may be degassed from water discharged from the quench tower and sent to the SRU furnace.
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
Systems and methods include techniques for using smart polymers. Units of smart polymers with per-hydrogen (pH) sensitivity are inserted into drilling fluid pumped into a well during drilling. The smart polymers are configured to be triggered by hydrogen ion concentrations. An insertion timestamp associated with each unit is stored and indicates a time that each unit was inserted. Continuous images and observed characteristics of returning mud exiting through an annulus of the well and containing the units of smart polymer are captured by a camera positioned at a sensing location and linked to the monitoring system. An estimate of pH values at a drill bit of the drilling operation is determined using the continuous images, observed characteristics, and insertion timestamps, and based at least in part on executing image processing algorithms, machine-learning models, and deep-learning models. Changes to be made to drilling parameters are suggested.
A system and method for producing hydrogen, including steam reforming elemental sulfur to generate hydrogen gas and sulfur dioxide, to give a mixture including hydrogen gas, sulfur dioxide, elemental sulfur gas, and water vapor, removing the elemental sulfur gas to give a process gas including the hydrogen gas, sulfur dioxide, and water vapor, and isolating the hydrogen gas or a hydrogen gas rich stream.
C01B 3/06 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of inorganic compounds containing electro-positively bound hydrogen, e.g. water, acids, bases, ammonia, with inorganic reducing agents
B01D 53/00 - 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
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
B01J 19/00 - Chemical, physical or physico-chemical processes in general; Their relevant apparatus
B01J 19/24 - Stationary reactors without moving elements inside
C01B 3/50 - Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
C01B 3/52 - Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification by contacting with liquids; Regeneration of used liquids
55.
METHOD OF WATERFLOODING USING INJECTION SOLUTIONS CONTAINING DIHYDROGEN PHOSPHATE
Provided are methods of increasing the production of a hydrocarbon from a subterranean formation by waterflooding with injection solutions containing dihydrogen phosphate ions.
A method of analyzing a geologic sample includes illuminating the geologic sample with a light beam and capturing an image of the geologic sample on a hyperspectral camera as a greyscale image, R-G-B color space image, or both, thereby collecting spectra having mid-wave infrared wavelengths or ultraviolet wavelengths reflected from a surface of the geologic sample. The method further includes processing the image to transform the image from the R-G-B color space, greyscale image, or both, and analyzing the Intensity to determine mineralogy, organic content, hydrocarbon presence, or combinations thereof of the geologic sample.
G01N 21/33 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using ultraviolet light
G01N 21/35 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light
G06V 10/143 - Sensing or illuminating at different wavelengths
G06V 10/50 - Extraction of image or video features by summing image-intensity values; Projection analysis
G06V 10/75 - Image or video pattern matching; Proximity measures in feature spaces using context analysis; Selection of dictionaries
H04N 9/67 - Circuits for processing colour signals for matrixing
H04N 23/11 - Cameras or camera modules comprising electronic image sensors; Control thereof for generating image signals from different wavelengths for generating image signals from visible and infrared light wavelengths
A system and method for removing sulfur compounds from gas, including providing a feed gas having sulfur compounds including hydrogen sulfide (H2S) to a sulfur recovery unit (SRU) that has a furnace or a non-thermal plasma (NTP) reactor, discharging an SRU tail gas having H2S from the SRU to a tail gas treatment (TGT) unit having a hydrogenation reactor, a quench tower, and a TGT NTP reactor, converting sulfur compounds in the SRU tail gas in the hydrogenation reactor into H2S, discharging a process gas having H2S from the hydrogenation reactor to the quench tower and removing water vapor from the process gas in the quench tower, discharging an overhead gas having H2S from the quench tower to the TGT NTP reactor, and converting H2S in the TGT NTP reactor into hydrogen (H2) and elemental sulfur.
Systems and methods include a technique for drilling and fracturing wells. Geomechanical properties and in-situ stresses for the field are estimated using collected data and results from mini-fracking tests. A 3D geomechanics model for the field is generated based on 3D property model and natural fracture network. First 3D hydraulic fracturing modeling for a single well is conducted to obtain an optimum pump schedule for a target fracture length and well spacing for placing numerous horizontal wells in the field. Then 3D hydraulic fracturing modeling for the multiple wells is conducted based on a drilling-fracturing sequence configured to generate symmetric fractures and to determine an optimum pump schedule for middle wells, considering tensile stress superposition. The drilling-fracturing sequence includes initially skipping fracturing of a drilled well adjacent to a fractured well. The group of wells are drilled and fractured using the sequence.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 43/17 - Interconnecting two or more wells by fracturing or otherwise attacking the formation
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
A method to perform an inflow negative test of a wellbore is disclosed. The method includes disposing a flow measuring sub in a drill string to mechanically connect a drill pipe joint and a drill pipe, and sustaining a fluid flow downstream along an annulus and upstream along the drill pipe. The fluid flow reverses direction through an open port in a wall of the drill pipe or an open end of the drill pipe, and returns to a mud tank from the drill pipe through the flow measuring sub and the drill pipe joint. Flow measurement data of fluid movement through the flow measuring sub is generated using a measuring device of the flow measuring sub and sent to a computer device of the flow measuring sub. Accordingly, a success/failure result of the inflow negative test is determined using the computer device based at least on the flow measurement data.
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 47/007 - Measuring stresses in a pipe string or casing
60.
PROCESS PUMPS AND RELATED METHODS OF TREATING A PROCESS LINE
A method of treating a fluid within a process line includes flowing a treatment chemical and a first volume of the fluid into an injection chamber of a process pump, exerting an upward force on a lower cylinder of a piston of the process pump with a mixture of the treatment chemical and the first volume of the fluid within the injection chamber, exerting a downward force on an upper cylinder of the piston with a second volume of the fluid, and transmitting the downward force to the lower cylinder of the piston to force the mixture out of the injection chamber and into the process line.
F04B 9/113 - Piston machines or pumps characterised by the driving or driven means to or from their working members the means being fluid the fluid being liquid having plural pumping chambers with two mechanically connected pumping members reciprocating movement of the pumping members being obtained by a double-acting liquid motor
F04B 5/02 - Machines or pumps with differential-surface pistons with double-acting pistons
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
Inventor
Nasser, Rayan M.
Alaama, Subhi A.
Rayaan, Muhammad B.
Tawabini, Bassam S.
Awadh, Tawfik A.
Abstract
An adsorption composition that includes a treatment agent including a material having an oxidized surface functionality and a carrier fluid are described. A method of preparing an adsorption composition including processing a material derived from at least one component of a date tree to provide a processed date tree material, treating the processed date tree material with a first treatment to produce a treated date tree material, reacting the treated date tree material with one or more oxidizing agents to form a treatment agent, and suspending the treatment agent in a carrier fluid is also described. Further, a method of adsorbing one or more compounds from a water-based fluid including introducing an adsorption composition to a water-based fluid containing one or more organic compounds contacting the adsorption composition with the one or more organic compounds and adsorbing the one or more organic compounds on the treatment agent is also described.
B01J 20/20 - Solid sorbent compositions or filter aid compositions; Sorbents for chromatography; Processes for preparing, regenerating or reactivating thereof comprising inorganic material comprising carbon obtained by carbonising processes
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
A valve assembly that includes a gate valve and an injection fitting. The gate valve has a lower body disposed between and fluidly coupled to a first pipe and a second pipe. The first pipe resides upstream of the lower body and the second pipe resides downstream of the lower body. The injection fitting is coupled to a side of the lower body of the gate valve. The injection fitting receives a sealing fluid to be flowed to the lower body of the gate valve to seal at least a portion of the gate valve.
F16K 39/04 - Devices for relieving the pressure on the sealing faces for sliding valves
F16K 3/30 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing - Details
63.
DETERMINING A THREE-DIMENSIONAL FRACABILITY INDEX FOR IDENTIFYING FRACABLE AREAS IN A SUBSURFACE REGION
Systems, methods, and software can be used for identifying fracable areas. One example of a method includes receiving at least one of 3D petrophysical property and 3D geo-mechanical property in one or more areas. The method further includes receiving a model generating at least one hydraulic fracture parameter in a wellbore in the one or more areas. The method yet further includes training a machine learning model with at least one of the 3D petrophysical property and the 3D geo-mechanical property and the at least one hydraulic fracture parameter, and generating a fracability index for the wellbore based on the trained machine learning model.
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 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
64.
ESTIMATING PRODUCTIVITY AND ESTIMATED ULTIMATE RECOVERY (EUR) OF UNCONVENTIONAL WELLS THROUGH SPATIAL-PERFORMANCE RELATIONSHIP USING MACHINE LEARNING
Systems and methods include an importance that each of the attributes and features of the well data has on machine learning models. Well data is collected for each well in an unconventional field, including attributes and features of basin data, completion data, and production data. Spatial features are generated for each well in different regions. A combined well features dataset is generated. The dataset maps the well data to the spatial features for each well in the different regions. A training dataset and a testing dataset are generated by splitting the combined dataset. A machine learning model is trained using cross-validation and tuning on the training dataset to predict estimated ultimate recovery (EUR). The performance of a machine learning (EUR) model is evaluated with respect to different regression metrics. An importance that each of the attributes and features of the well data has on machine learning models is determined.
Systems and methods for providing artificial lift to wellbore fluids includes a pump, a motor, and a protector assembly forming an electric submersible pump system located in a wellbore. A solids isolator is located between the pump and the protector assembly. The solids isolator includes a tubular discharge body with an inner discharge bore. A body port extends through a sidewall of the discharge body. A sliding seal member is located within the discharge bore and moveable between a port open position where the body port is open to allow fluids to travel through the body port, and a port closed position, where fluids are prevented from traveling through the body port. The sliding seal member is ring shaped in cross section. The sliding seal member is biased to the port closed position when the pump is off and moveable to the port open position when the pump is on.
Systems and methods for providing artificial lift to wellbore fluids includes a pump, a motor, and a protector assembly forming an electric submersible pump system located within a wellbore. A downhole packer is located downhole of the pump. A solids bypass device is located downhole of the pump. The solids bypass device has a flow tube with an inner bore, a bypass stinger that is a tubular member that circumscribes the flow tube, and drain ports extending through a sidewall of the bypass stinger. A sealing cap circumscribes the flow tube. The sealing cap is moveable between an open position, where the sealing cap is positioned to provide an external fluid flow path through the solids bypass device, and a closed position, where the sealing cap prevents fluid from traveling through the external fluid flow path. A biasing member biases the sealing cap towards the open position.
A system and method of regenerating triethylene glycol (TEG) in natural gas dehydration, including removing water from TEG in a TEG regeneration still column having a fired-heater reboiler that includes a burner and a reboiler vessel. The TEG bath temperature in the reboiler vessel and the oxygen gas content in a stack effluent from the burner are controlled automatically via a control system adjusting flow of air and fuel to the burner while maintaining a specified weight ratio of the air to the fuel.
A method and an unmanned surface vehicle for identifying and remediating a gas leak. The method includes detecting a first condition indicative of the gas leak with a first sensor and sensing environmental conditions near the gas leak with an environmental sensor. The method includes receiving, at a controller operatively coupled to the unmanned surface vehicle, signals representing the first condition indicative of the gas leak the environmental conditions near the gas leak. The method includes determining, by the controller and based on the first condition indicative of the gas leak and the environmental conditions near the gas leak, a navigation plan of the body of water including an ignition zone. The method includes positioning, based on the navigation plan, the unmanned surface vehicle relative to the ignition zone and discharging, by an ignition mechanism, an ignition source into the gas leak to ignite the gas leak.
A method and an unmanned aerial vehicle for identifying and remediating a gas leak. The method includes flying the unmanned aerial vehicle towards a possible location of the gas leak, then detecting a first condition indicative of the gas leak with a first sensor and sensing environmental conditions near the gas leak with an environmental sensor. The method includes receiving, by a controller, a signal representing the first condition indicative of the gas leak and a signal representing the environmental conditions. The method includes determining, based on the first condition indicative of the gas leak and the environmental conditions near the gas leak, a flight plan including an ignition zone. The method includes positioning, based on the flight plan, the unmanned aerial vehicle relative to the ignition zone and discharging, by an ignition mechanism, an ignition source into the gas leak to ignite the gas leak.
G05D 1/10 - Simultaneous control of position or course in three dimensions
B64C 39/02 - Aircraft not otherwise provided for characterised by special use
B64D 35/04 - Transmitting power from power plant to propellers or rotors; Arrangements of transmissions characterised by the transmission driving a plurality of propellers or rotors
A method for controlling a wellbore pressure. The method includes disposing a tubing within a casing of a wellbore to form a tubing casing annulus. The method includes installing a tubing-packer sealing assembly within the casing to seal a downhole portion of the wellbore from an uphole portion. The tubing is disposed in the uphole portion of the wellbore. The method includes filling the tubing casing annulus in with an annulus fluid. The method includes, after filling the tubing casing annulus with the annulus fluid, injecting a volume of inert gas into the tubing casing annulus causing an equal volume of the tubing casing annulus fluid to be flowed out of the wellbore. The method includes after injecting the volume of the inert gas, sealing the annulus fluid and the inert gas in the tubing casing annulus.
A hydrocarbon feed stream is exposed to heat in an absence of oxygen to the convert the hydrocarbon feed stream into a solids stream and a gas stream. The gas stream is separated into an exhaust gas stream and a first hydrogen stream. The carbon is separated from the solids stream to produce a carbon stream. Electrolysis is performed on a water stream to produce an oxygen stream and a second hydrogen stream. A solid carbon block is formed. Alumina is smelted using the solid carbon block to produce aluminum. At least a portion of the oxygen of the oxygen stream and a second portion of the carbon of the carbon stream are combined to generate power and a carbon dioxide stream. At least a portion of the aluminum and a third portion of the carbon of the carbon stream are combined and heated to produce aluminum carbide.
H01M 8/1233 - Fuel cells with solid electrolytes operating at high temperature, e.g. with stabilised ZrO2 electrolyte with one of the reactants being liquid, solid or liquid-charged
H01M 8/22 - Fuel cells in which the fuel is based on materials comprising carbon or oxygen or hydrogen and other elements; Fuel cells in which the fuel is based on materials comprising only elements other than carbon, oxygen or hydrogen
72.
CO-PRODUCTION OF HYDROGEN, CARBON, ELECTRICITY, AND CARBON MONOXIDE WITH CARBON DIOXIDE CAPTURE FOR REFINING OF CRUDE OIL
A crude oil is processed to form a hydrocarbon feed stream. The hydrocarbon feed stream is exposed to heat in an absence of oxygen to the convert the hydrocarbon feed stream into a solids stream and a gas stream. The gas stream is separated into an exhaust gas stream and a first hydrogen stream. The carbon is separated from the solids stream to produce a carbon stream. Electrolysis is performed on a water stream to produce an oxygen stream and a second hydrogen stream. At least a portion of the oxygen of the oxygen stream and a second portion of the carbon of the carbon stream are combined to generate power and a carbon dioxide stream. The carbon dioxide is used in dry reforming to produce syngas.
C01B 3/32 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air
C01B 3/24 - Production of hydrogen or of gaseous mixtures containing hydrogen by decomposition of gaseous or liquid organic compounds of hydrocarbons
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Almaskeen, Lyla
Alsofi, Abdulkareem
Xu, Limin
Abstract
A method includes providing a gelant including a cross-linkable polymer, a crosslinking agent and an aqueous fluid, adding one or more fluorescent rare earth elements to the gelant to provide a fluorescent gelant solution in which a fluorescence emission is quenched, and initiating crosslinking of the gelant to form a gel by heating the fluorescent gelant solution. The intensity of the fluorescence emission of the fluorescent gelant solution is monitored as an indicator of gelation status and a gelation point of the gelant may be identified based on the intensity of the fluorescent emission of the fluorescent gelant solution.
King Abdullah University of Science and Technology (Saudi Arabia)
Inventor
Hodgkins, Robert Peter
Koseoglu, Omer Refa
Basset, Jean-Marie Maurice
Huang, Kuo-Wei
Sedjerari, Anissa Bendjeriou
Murugesan, Sathiyamoorthy
Gangwar, Manoj K.
Abstract
Disclosed herein are modified zeolites and methods for making modified zeolites. In one or more embodiments disclosed herein, a modified zeolite may include a microporous framework including a plurality of micropores having diameters of less than or equal to 2 nm. The microporous framework may include at least silicon atoms and oxygen atoms. The modified zeolite may further include organometallic moieties each bonded to a nitrogen atom of a secondary amine functional group comprising a nitrogen atom and a hydrogen atom. The organometallic moieties may comprise a hafnium atom that is bonded to the nitrogen atom of the secondary amine functional group. The nitrogen atom of the secondary amine function group may bridge the hafnium atom of the organometallic moiety and a silicon atom of the microporous framework.
C01B 39/02 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof; Direct preparation thereof; Preparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactants; After-treatment thereof
75.
Treatment fluid recipe for high temperature multi-stage fracturing applications
Provided is a composition that may include a fluid formulation that is a water-in-oil emulsion, having an organic phase and an aqueous phase, the aqueous phase dispersed in the organic phase. The organic phase may include an organic solvent, an emulsifier, and a wetting agent. The aqueous phase may include water, a chelating agent, and a base. Further provided is a method that may include introducing the composition into a wellbore as a single stage treatment, maintaining the wellbore by shutting-in the well, and hydraulic fracturing the wellbore.
Systems and methods include a computer-implemented method for determining well pressure. Units of pressure-responsive smart polymers are inserted into drilling fluid pumped into a well during a drilling operation. An insertion timestamp associated with each unit is stored indicating times that each unit was inserted. Continuous images and observed characteristics of drilling mud exiting through an annulus of the well and containing the units of smart polymers are captured by a camera. An estimate of a bottom hole pressure (BHP) at a drill bit of the drilling operation is determined using the continuous images, the observed characteristics, and the insertion timestamps associated with each unit of smart polymer. Determining the estimate is based at least in part on executing image processing algorithms, machine-learning models, and deep-learning models. Changes to be made to drilling parameters for the drilling operation are suggested based on the estimated BHP.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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 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
Embodiments of the present disclosure are directed to a method of processing a hydrocarbon feed includes fractionating the hydrocarbon feed into a light stream and a heavy stream, hydrotreating the heavy stream to form a hydrotreated heavy stream, combining the light stream and the hydrotreated heavy stream to form a upgraded feed stream, and feeding the upgraded feed stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream comprising light olefins. The light stream may comprise hydrocarbons boiling at less than 343° C. and the heavy stream may comprise hydrocarbons boiling at greater than 343° C. The FCC reaction zone may be operated in a down-flow configuration and the FCC may be operated under high severity conditions.
C10G 67/14 - 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 at least two different refining steps in the absence of hydrogen
Solidified nitrogen is placed at a downhole location within a wellbore formed in a subterranean formation. The solidified nitrogen is encapsulated by an emulsifying agent. The emulsifying agent is configured to dissolve in response to exposure to a downhole fluid. The solidified nitrogen encapsulated by the emulsifying agent is exposed to the downhole fluid at the downhole location within the wellbore, thereby dissolving the emulsifying agent and releasing the solidified nitrogen. The solidified nitrogen is allowed to sublimate into nitrogen gas within the wellbore, thereby reducing hydrostatic column in the wellbore. The downhole fluid is produced from the wellbore to a surface location.
This disclosure relates to methods of treating the surface of a metal casing, such as a casing used in a wellbore. The disclosure also relates to methods of increasing the bond strength between cement and a metal casing surface treated with a reactive organic compound.
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
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C23C 22/60 - Chemical surface treatment of metallic material by reaction of the surface with a reactive liquid, leaving reaction products of surface material in the coating, e.g. conversion coatings, passivation of metals using aqueous solutions using alkaline aqueous solutions with pH > 8
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
A composition that includes an oil-soluble carbon dot and an organic fluid is provided. The oil-soluble carbon dot includes a transition metal, a rare earth element, or a combination of both. A method of making the oil-soluble carbon dot is also provided. The method includes combining an organic reactant, an amine, a dehydrating agent, and a hydrophobic organometallic compound to form a mixture, and heating the mixture such that the oil-soluble carbon dot forms. A method of determining a flow characteristic of a formation or an attribute of a fluid in a formation using the oil-soluble carbon dots is also provided.
A thermoplastic pipe and a method for producing it are described. The thermoplastic pipe includes a hollow inner liner layer, a semi-consolidated core comprising commingled fibers, and a shrink wrap outer layer. The commingled fibers comprise at least one thermoplastic fiber and at least one reinforcing fiber. The semi-consolidated core layer comprises a thermoplastic polymer matrix that is organized along the at least one reinforcing fiber. The method includes winding commingled fibers over the hollow inner liner layer at a designated angle to produce a core layer, covering the core layer in a heat shrinkable wrap, and heating to produce a semi-consolidated core layer. The semi-consolidated core layer comprises a thermoplastic polymer matrix that is organized along the at least one reinforcing fiber.
B29C 63/00 - Lining or sheathing, i.e. applying preformed layers or sheathings of plastics; Apparatus therefor
B29C 63/34 - Lining or sheathing of internal surfaces using tubular layer or sheathings
B29C 70/22 - Fibrous reinforcements only characterised by the structure of fibrous reinforcements using fibres of substantial or continuous length oriented in at least two directions forming a two dimensional structure
B29C 70/30 - Shaping by lay-up, i.e. applying fibres, tape or broadsheet on a mould, former or core; Shaping by spray-up, i.e. spraying of fibres on a mould, former or core
B32B 5/08 - Layered products characterised by the non-homogeneity or physical structure of a layer characterised by structural features of a layer comprising fibres or filaments the fibres or filaments of a layer being specially arranged or being of different substances
B32B 5/12 - Layered products characterised by the non-homogeneity or physical structure of a layer characterised by structural features of a layer comprising fibres or filaments characterised by the relative arrangement of fibres or filaments of adjacent layers
B32B 27/08 - Layered products essentially comprising synthetic resin as the main or only constituent of a layer next to another layer of a specific substance of synthetic resin of a different kind
B32B 27/12 - Layered products essentially comprising synthetic resin next to a fibrous or filamentary layer
B32B 37/06 - Methods or apparatus for laminating, e.g. by curing or by ultrasonic bonding characterised by the heating method
B32B 37/14 - Methods or apparatus for laminating, e.g. by curing or by ultrasonic bonding characterised by the properties of the layers
B32B 37/20 - Methods or apparatus for laminating, e.g. by curing or by ultrasonic bonding characterised by the properties of the layers with all layers existing as coherent layers before laminating involving the assembly of continuous webs only
A system and a process for reducing greenhouse gas emissions are disclosed herein. The system may include a combustion zone, a catalytic converter, a methanation reactor, a compressor, a normal venting unit, a vacuum protection unit, and a control system. The process may include feeding a fuel, a methane-containing gas, and an oxygen-containing gas into a first reactor unit, and producing a combustion products stream comprising carbon monoxide, carbon dioxide, and water. The process may include cooling the combustion products stream via a cooling system, feeding the cooled exhaust stream and hydrogen to a second reactor unit. The second reactor unit may include a first catalyst for reacting oxygen with carbon monoxide to form carbon dioxide, and a second catalyst for reacting carbon dioxide with hydrogen to produce methane. The process may include recovering an effluent from the second reactor unit and feeding it to the first reactor unit.
C07C 1/12 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon from oxides of carbon from carbon dioxide with hydrogen
83.
SYSTEM AND METHOD FOR MONITORING A COMPUTER RESOURCE ASSET USING A SMART CONTRACT AND A NEURAL NETWORK
A system and method monitor a computer resource asset for vulnerability and security weaknesses using a smart contract and a neural network. The system comprises a processor configured to receive data from a data source, a memory configured to store current smart contract baseline data, an artificial neural network including a plurality of nodes configured as a plurality of layers to determine a new data feed in the received data and to update the current smart contract baseline data, a smart contract monitoring subsystem configured to monitor a computer resource asset using the current smart contract baseline data, and a remediation subsystem configured to remediate access of the computer resource asset to a computer network. The method implements the system.
A method for regenerating carbon dioxide and hydrogen sulfide from acid gas using a catalyst containing a group 2 element is provided. The method reduces the energy required for the regeneration process and allows for an efficient and cost-effective way to regenerate acid gas.
A method for using an accelerated solvent extractor to study ion reaction parameters is provided. The method includes entering a solution mixture and reaction parameters for each of a plurality of extraction cells, wherein the solution mixture includes a ratio of a first ion solution to a second ion solution. The solution mixture is reacted in each of the plurality of extraction cells at the reaction parameters for that extraction cell. Effluent and solids are collected from each of the plurality of extraction cells. The effluent and the solids are analyzed to obtain composition results. The composition results are correlated to the solution mixture for each of the plurality of extraction cells and the reaction parameters for each of the plurality of extraction cells.
A method for mapping inter-well porosity includes injecting a Type 1 tracer into a hydrocarbon-bearing reservoir via an injector well, wherein the Type 1 tracer is a passive tracer, injecting a Type 2 tracer into the hydrocarbon-bearing reservoir via the injector well, wherein the Type 2 tracer is a porosity-sensitive tracer, detecting a breakthrough of the Type 1 tracer and a breakthrough of the Type 2 tracer in produced fluid at a producer well, and comparing the breakthrough of the Type 1 tracer with the breakthrough of the Type 2 tracer to provide a map of inter-well porosity.
E21B 47/11 - Locating fluid leaks, intrusions or movements using radioactivity
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
87.
QUANTIFICATION OF PORE-FILLING DOLOMITE AND CALCITE CEMENT IN CARBONATE RESERVOIRS IN POST HYDROCARBON CHARGE STAGE
A method is disclosed, where the method includes obtaining a water-leg sample from a carbonate facies and an oil-leg sample from the carbonate facies and determining a characteristic of a cement in each sample. The method further includes determining a volume of cement in each sample and determining a binary change flag indicating a temporal change in pore water geochemistry based, at least in part, on the volume and the characteristic of the cement in each sample.
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 49/02 - 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 by mechanically taking samples of the soil
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
88.
DYNAMIC REAL TIME GROSS RATE MONITORING THROUGH SUBSURFACE AND SURFACE DATA
Continuous gross rate of each of a plurality of wells is estimated. Information provided by sensors configured with each of a plurality of electrical submersible pumps is received. Information associated with a respective model of each of the plurality of electrical submersible pumps is accessed. Utilizing at least one of artificial intelligence and machine learning, the information provided by sensors and the information associated with the respective model of each of the plurality of electrical submersible pumps is processed to estimate a first gross rate of each of the plurality of wells. A second gross rate of each of the plurality of wells is estimated via a pipeline simulation that applies a physics-based model. A continuous gross rate for each of the plurality of wells is estimated as a function the first gross rate and the second gross rate.
A method includes deploying a cementing assembly within a wellbore that is at least partially open hole. The method also includes setting the cementing assembly at a target zone of the wellbore by setting a first packer of the cementing assembly downhole of the target zone. The method also includes flowing, through the wellbore string and through the cementing assembly, cement to an annulus at the target zone. The annulus is defined between an exterior surface of the cementing assembly and a wall of the wellbore. The method also includes setting, with the wellbore string, a second packer of the cementing assembly. The second packer is disposed uphole of the first packer and uphole of the target zone.
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
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
90.
Co-production of Hydrogen and Sulfuric Acid by Partial Oxidation of Sulfur
A system and method for producing hydrogen, including converting sulfur vapor and oxygen gas in a first zone of furnace into sulfur monoxide, injecting water into a second zone of the furnace, converting the sulfur monoxide and the water in the second zone into hydrogen gas and sulfur dioxide, discharging furnace exhaust gas (including the hydrogen gas) from the furnace, condensing sulfur vapor in the furnace exhaust gas into liquid sulfur in a condenser (heat exchanger) downstream of the furnace, and discharging the liquid sulfur from the condenser to a vessel.
C01B 3/06 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of inorganic compounds containing electro-positively bound hydrogen, e.g. water, acids, bases, ammonia, with inorganic reducing agents
C01B 3/52 - Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification by contacting with liquids; Regeneration of used liquids
A method for subsurface sequestration of carbon in a subterranean zone includes forming a fluid-filled volume in the subterranean zone by injecting an aqueous into the subterranean zone and injecting a mixture comprising silicate nanoparticles suspended in an acidic solution having a pH of less than 4. Carbon in the form of carbon dioxide is injected into the fluid-filled volume such that a least a portion of the carbon is sequestered by precipitation of carbonate minerals. At least a portion of the carbonate minerals are formed from reaction of metal cations with bicarbonate formed from the carbon dioxide, and least a portion of the metal cations are a product of decomposition of the silicate nanoparticles in the acidic solution.
Systems and methods for sealing concrete are provided. An exemplary multilayer concrete sealant includes a first layer disposed over a concrete surface, wherein the first layer includes an epoxy nanocomposite, and a second layer disposed over the epoxy nanocomposite, wherein the second layer includes a polyurethane microcomposite.
A method of fracturing a subsurface formation includes super-cooling liquid carbon dioxide to a temperature between −60° F. to −70° F. using liquid nitrogen having a temperature in a range of −100° F. to −200° F., pumping the lipid carbon dioxide down a wellbore to create fractures in the subsurface formation, and pumping fracturing fluid containing a proppant down the wellbore after pumping the liquid carbon dioxide down the wellbore.
Systems and methods for cleaning an internal bore of a tubular member with a pipeline pig include a pipeline pig having a pig body with a fore end and an aft end opposite the fore end. A cup circumscribes the pig body, where an outer diameter lip of the cup engages a surface of the internal bore of the tubular member. A scraper assembly includes a scraper arm extending radially outward from the pig body and a spring biasing the scraper arm in a radially outward direction. A load cell is positioned to measure a movement of the scraper arm in a radially inward direction. A treatment trigger is actuated by a treatment signal from the load cell to deliver a treatment system to the internal bore of the tubular member, where the treatment signal is generated by the movement of the scraper arm in the radially inward direction.
B08B 9/055 - Cleaning the internal surfaces; Removal of blockages using cleaning devices introduced into and moved along the pipes moved along the pipes by a fluid, e.g. by fluid pressure or by suction the cleaning devices conforming to, or being conformable to, substantially the cross-section of the pipes, e.g. pigs or moles
A method for operating a conduit inspection tool in a conduit includes positioning a conduit inspection tool in the conduit, the conduit inspection tool including a body that includes one or more wheels, at least two power generating sub-systems coupled to the body, and at least one energy storage device electrically coupled to the at least two power generating sub-systems; moving the body through and in contact with the conduit through the one or more wheels; generating electrical power by at least one of the at least two power generating sub-systems by the movement; and providing at least a portion of the generated electrical power to the at least one energy storage device to store the portion of the generated electrical power.
B08B 9/049 - Cleaning the internal surfaces; Removal of blockages using cleaning devices introduced into and moved along the pipes having self-contained propelling means for moving the cleaning devices along the pipes
B60L 50/30 - Electric propulsion with power supplied within the vehicle using propulsion power stored mechanically, e.g. in fly-wheels
B60L 50/53 - Electric propulsion with power supplied within the vehicle using propulsion power supplied by batteries or fuel cells in combination with an external power supply, e.g. from overhead contact lines
B60L 50/60 - Electric propulsion with power supplied within the vehicle using propulsion power supplied by batteries or fuel cells using power supplied by batteries
B60L 50/90 - Electric propulsion with power supplied within the vehicle using propulsion power supplied by specific means not covered by groups , e.g. by direct conversion of thermal nuclear energy into electricity
F16L 55/32 - Constructional aspects of the propulsion means, e.g. towed by cables being self-contained
H02K 7/02 - Additional mass for increasing inertia, e.g. flywheels
H02K 7/116 - Structural association with clutches, brakes, gears, pulleys or mechanical starters with gears
96.
Conversion of whole crude to value added petrochemicals in an integrated reactor process
An integrated process and associated system for conversion of crude oil to value added petrochemicals. The process includes separating crude oil into light and heavy crude fractions and processing the heavy fraction in a solvent deasphalting unit and a delayed coker unit, and then providing the light fraction and selected effluents of the solvent deasphalting unit and the delayed coker unit to a hydrotreater. The process further includes separating the effluent of the hydrotreater to generate a C1 fraction passed to a methane cracker, a C2 fraction passed to an ethane steam cracker, a C3-C4 fraction passed to a dehydrogenation reactor, a hydrotreated light fraction passed to an aromatization unit, and a hydrotreated heavy fraction passed to a steam enhanced catalytic cracking unit. The process further includes separating effluents of the various unit operations into product streams including a BTX stream and a light olefin stream.
C10G 67/04 - 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 solvent extraction as the refining step in the absence of hydrogen
C07C 2/76 - Preparation of hydrocarbons from hydrocarbons containing a smaller number of carbon atoms by condensation of hydrocarbons with partial elimination of hydrogen
C07C 5/32 - Preparation of hydrocarbons from hydrocarbons containing the same number of carbon atoms by dehydrogenation with formation of free hydrogen
C10G 9/00 - Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
97.
Rapid Identification of Hydrodynamic Traps in Hydrocarbon Reservoirs
Example computer-implemented methods, media, and systems for rapidly identifying hydrodynamic traps in hydrocarbon reservoirs are disclosed. One example computer-implemented method includes receiving a depth structure map of a geological structure associated with a subsurface reservoir. Multiple pairs of tilt value and tilt azimuth value associated with a fluid contact of the subsurface reservoir are received. A respective set of hydrodynamic traps associated with the subsurface reservoir is determined for each pair of tilt value and tilt azimuth value and based at least on the depth structure map. It is determined that there exist a common subset of hydrodynamic traps from the respective set of hydrodynamic traps of each pair of tilt value and tilt azimuth value. One or more locations of potential wells associated with the subsurface reservoir are identified based at least on the determined common subset of hydrodynamic traps.
A computer-implemented method for quantitative prediction and sorting of carbon underground treatment and sequestration is described. The method includes preprocessing multiple data sets, wherein the multiple datasets are multi-modal and multiscale data sets. The method also includes predicting geological structural properties, chemical properties, and geological properties by inputting the preprocessed multiple data sets into trained machine learning models. Additionally, the method includes ranking the storage and treatment potential of a formation based on the predicted geological structural properties, chemical properties, and geological properties.
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
99.
AQUEOUS FLUID COMPOSITIONS AND BARITE SCALE REMOVAL THEREWITH
Barite (barium sulfate) scale may be problematic in subterranean formations, wellbores, pipelines, and other locations and may be difficult to remove in many instances. Aqueous fluid compositions effective for removing barite scale may comprise a concentrated mineral acid, a first salt comprising an iodide anion, and a second salt comprising an anion that forms an aqueous-soluble barium salt. One suitable aqueous fluid composition may comprise concentrated hydroiodic acid, an alkali metal iodide, and an alkali metal hypophosphite salt. The aqueous fluid compositions may be used in combination with a second treatment phase comprising a fluid composition comprising at least one acid gas capturing agent. The at least one acid gas capturing agent may comprise a first component reactive toward hydrogen sulfide and an optional second component reactive toward carbon dioxide.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
100.
SEMI-CONSOLIDATED REINFORCED THERMOPLASTIC PIPE WITH PREPREG REINFORCED CORE LAYER
A thermoplastic pipe and a method for producing a thermoplastic pipe are provided. The thermoplastic pipe includes a liner layer, a semi-consolidated core layer comprising a prepreg polymeric fabric layer, and a shrink wrap outer layer. The semi-consolidated core layer comprises a thermoplastic polymer matrix that is randomly distributed across the fabric. The method includes producing a hollow inner liner layer, winding a prepreg comprising a polymeric powder scattered on a fabric over the hollow inner liner layer to produce a core layer, covering the core layer in a heat shrinkable wrap, and heating to produce a semi-consolidated core layer. The semi-consolidated core layer comprises a thermoplastic polymer matrix that is randomly distributed across the fabric.
B29C 63/00 - Lining or sheathing, i.e. applying preformed layers or sheathings of plastics; Apparatus therefor
B29C 63/34 - Lining or sheathing of internal surfaces using tubular layer or sheathings
B29C 70/22 - Fibrous reinforcements only characterised by the structure of fibrous reinforcements using fibres of substantial or continuous length oriented in at least two directions forming a two dimensional structure
B32B 5/02 - Layered products characterised by the non-homogeneity or physical structure of a layer characterised by structural features of a layer comprising fibres or filaments
B32B 5/08 - Layered products characterised by the non-homogeneity or physical structure of a layer characterised by structural features of a layer comprising fibres or filaments the fibres or filaments of a layer being specially arranged or being of different substances
B32B 5/12 - Layered products characterised by the non-homogeneity or physical structure of a layer characterised by structural features of a layer comprising fibres or filaments characterised by the relative arrangement of fibres or filaments of adjacent layers
B32B 37/14 - Methods or apparatus for laminating, e.g. by curing or by ultrasonic bonding characterised by the properties of the layers
B32B 37/20 - Methods or apparatus for laminating, e.g. by curing or by ultrasonic bonding characterised by the properties of the layers with all layers existing as coherent layers before laminating involving the assembly of continuous webs only
patents
