Methods and systems are disclosed. The method may include obtaining a first plurality of hydrocarbon source rock samples from a first well and a second plurality of hydrocarbon source rock samples from a second well, each well penetrating a portion of a subterranean region. For each of the first and second plurality of samples obtaining a set of kinetic parameter values, including a discrete distribution of activation energy and a common frequency factor and determining a weighted average activation energy value from the distribution. The method may further include identifying a first chemostratigraphic segment of the first well and a second chemostratigraphic segment of the second well, each based on the weighted average activation values; determining a correlated stratigraphic unit and mapping organofacies based on the first the second chemostratigraphic segments; and predicting hydrocarbon generation, retention and expulsion and determining a drilling target within the correlated stratigraphic unit.
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
G01N 1/08 - Devices for withdrawing samples in the solid state, e.g. by cutting involving an extracting tool, e.g. core bit
Methods, systems, and computer-readable storage media for machine learning driven history-match quality assessment. Probe data collected by probes included in operating wells or observation wells within a field is received. A list of training dataset including examples of Good and Acceptable matches is received. Data density distribution a matching the probe data to simulated data for respective parameters is learned. Training parameters for subsequent history-match assessment from the labeled input for the respective parameters can be retrieved. A well history-match quality is determined within the field using the parameter match assessment to provide well planning within the field.
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]
3.
DISPENSING MICROPROCESSOR DEVICES FOR DOWNHOLE DATA COLLECTION
A drilling fluid system includes: at least one microprocessor device; a container that defines an interior volume; a container inlet that provides access for entry of the at least one microprocessor device into the interior volume of the container; a container outlet that provides egress for passage of the at least one microprocessor device from the interior volume of the container into a drilling fluid conduit of the drilling system; and a dispenser apparatus configured to controllably release the at least one microprocessor device through the container outlet into the drilling fluid conduit of the drilling system. The at least one microprocessor device includes a power source and one or more sensors configured to generate sensor data indicating downhole conditions of a well and to wirelessly transmit the sensor data to a computer at a terranean surface.
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
4.
PROCESS EQUIPMENT CRITICALITY ASSESSMENT AUTOMATION
A method to perform an equipment maintenance operation of a facility. The method includes obtaining, from an Asset Management Solution (AMS) or a Computerized Maintenance Management System (CMMS), a hierarchical equipment list of the facility, identifying, from the hierarchical equipment list, functional locations each comprising pieces of equipment assigned respective equipment attributes in the AMS or CMMS, retrieving, from the AMS or CMMS, the equipment attributes of all equipment deployed in the functional locations, analyzing the equipment attributes to generate a failure consequences score, an importance score, a reliability and maintainability score, and a utilization score of each of the functional locations, and facilitating, based on the failure consequences score, the importance score, the reliability and maintainability score, and the utilization score of each of the functional locations, the equipment maintenance operation of the facility.
Power line protection coordination schemes using pivotable multi-fuse assemblies includes multiple power line fuse assemblies deployed on a power line. Each fuse assembly includes multiple fuses that can be pivoted about an electrical connection point. Multiple fuses across the multiple power line fuse assemblies are tagged with a common visual code. Multiple such common visual codes are defined. Each common visual code maps to a protection coordination scheme to manage power flowed to loads on the power line. In turn, each protection coordination scheme is mapped to a direction of flow of power. Based on a chosen direction, a protection coordination scheme is identified. When the identified scheme is deployed, all fuses tagged with the visual code mapped to the scheme are deployed by pivoting fuses about the electrical connection point.
H01H 85/20 - Bases for supporting the fuseSeparate parts thereof
H01H 85/02 - Protective devices in which the current flows through a part of fusible material and this current is interrupted by displacement of the fusible material when this current becomes excessive Details
H01H 85/34 - Distinguishing marks, e.g. colour coding
H01H 85/54 - Protective devices wherein the fuse is carried, held, or retained by an intermediate or auxiliary part removable from the base, or used as sectionalisers
H02H 7/26 - Sectionalised protection of cable or line systems, e.g. for disconnecting a section on which a short-circuit, earth fault, or arc discharge has occurred
A fluid recapture system includes a translation sub-system, a recirculation sub-system, and an energy conversion sub-system. The translation sub-system a moveable platform on which the recirculation sub-system and energy conversion sub-system are mounted. The recirculation sub-system includes a fluid line having a first end, a second end, and a fluid channel extending from the first end to the second end. The translation sub-system also includes a basin attached to the second end of the fluid line and a fluid pump disposed on the fluid line. The basin is fluidly connected to the fluid channel of the fluid line. The fluid pump is operable to convey fluid from the basin to the first end of the fluid line. The energy conversion sub-system includes a turbine aligned with the basin and a transmission connected to the fluid pump and connected to the turbine. The transmission is operable to power the pump.
Described is a method for marine vessel shipment management. A loading plan with supplies to be shipped on a marine vessel is presented to a user interface of a mobile communication device in communication with other mobile communication devices. Using the user interface, a modifiable passage plan is selected for the loading plan. The passage plan includes a route to an intended destination for delivery of the supplies. Upon delivery of the supplies to the intended destination, a notice of delivery is obtained via the user interface of one or more of the mobile communication devices.
Methods, systems, and computer-readable storage media for receiving, from probes, probe data indicative of gas storage, the probe data being collected by probes included in operating wells and observation wells within a field, the probe data comprising surface data and subterranean data indicative of a health of a gas storage reservoir within the field. A gas storage status is determined by using a gas storage model, the gas storage model correlating the surface data and the subterranean data within the field. A gas storage assessment report including a pressure map reflecting the gas storage status within the field is provided.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A wellbore system includes coiled tubing extending into a wellbore from a surface location and a downhole tool coupled to a downhole end of the coiled tubing. A cable extends through the coiled tubing and is operably coupled to the downhole tool within the wellbore. An insert is disposed within the coiled tubing and engages the cable. The insert includes a plurality of elongated rods radially spaced around the cable and defining a longitudinal axis of the insert, and a plurality of retractable bars extending radially inwardly from the elongated rods. The retractable bars are biased radially inward to an extended position wherein the retractable bars flex the cable into an undulating configuration with respect to the longitudinal axis, and the retractable bars are responsive to an increased tension in the cable to move radially outward to a retracted configuration.
E21B 19/22 - Handling reeled pipe or rod units, e.g. flexible drilling pipes
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
10.
INSULATION GASKET WITH RTJ SEAL FOR RTJ FLANGES IN HIGH-PRESSURE PIPING
DELMON INDUSTRIAL AND MECHANICAL INSULATION FACTORY CO. (Saudi Arabia)
Inventor
Almana, Mohammed S.
Alsaqr, Tawfeeq S.
Alharbi, Ali A.
Hanglur, Usman
Abstract
A system and an apparatus for a new design for an insulation gasket with RTJ seal for RTJ flanges in high-pressure piping are disclosed. The system includes a first pipe and a second pipe, configured to be sealed together; and an apparatus, comprising: a ring type joint (RTJ) flange, and a insulation gasket with RTJ seal, wherein the insulation gasket with RTJ seal comprises a metal core, insulating sleeves, insulating washers, metallic back up washers, and a polytetrafluoroethylene (“PTFE”) seal for RTJ grooves on either of its sides, configured to create a seal between the first pipe and the second pipe.
F16L 23/22 - Flanged joints characterised by the sealing means the sealing means being rings made exclusively of a material other than metal
F16J 15/06 - Sealings between relatively-stationary surfaces with solid packing compressed between sealing surfaces
F16J 15/10 - Sealings between relatively-stationary surfaces with solid packing compressed between sealing surfaces with non-metallic packing
F16J 15/12 - Sealings between relatively-stationary surfaces with solid packing compressed between sealing surfaces with non-metallic packing with metal reinforcement or covering
Carbon dioxide may be stored in a subterranean formation. For example, methods of subterranean carbon dioxide storage may include: introducing, through an injection region of a unified wellbore to a subterranean formation, a carbonated aqueous fluid including carbon dioxide dispersed within an aqueous fluid, wherein the subterranean formation includes a basaltic formation; reacting the carbon dioxide or an ion thereof with the basaltic formation to form mineralized carbon and a produced aqueous fluid; flowing a mixture of the carbonated aqueous fluid and the produced aqueous fluid through a delivery region of the unified wellbore; depositing the mineralized carbon dioxide within the subterranean formation; and flowing the produced aqueous fluid from the subterranean formation through a production region of the unified wellbore, wherein the injection region and the production region are substantially vertical, and wherein the delivery region is substantially horizontal.
Slickwater fracturing fluids comprising aqueous formate fluids may promote underground carbon storage. In an aspect, slickwater fracturing fluids may comprise: an aqueous formate fluid; proppant particulates; a friction reducer; and optionally, one or more additives. In an aspect, methods may comprise: introducing the slickwater fracturing fluid into a subterranean formation; contacting the slickwater fracturing fluid with a matrix of the subterranean formation; and retaining at least a portion of the formate anions within the subterranean formation. In an embodiment, methods may comprise introducing the slickwater fracturing fluid to the subterranean formation at a pressure and/or a flow rate sufficient to create and/or enlarge one or more fractures in the subterranean formation, and to force the slickwater fracturing fluid into the one or more fractures in the subterranean formation.
Microbial electrosynthesis (MES) may be used in converting carbon dioxide from a gas-oil separation plant (GOSP) to fixed carbon products. Example methods of MES may include: separating emitted carbon dioxide from an extracted gas-oil in a GOSP; dispersing the emitted carbon dioxide in a first portion of electrolyte solution in a cathode chamber of an electrolysis reactor; converting the emitted carbon dioxide to a fixed carbon product with a biocatalyst within the cathode chamber; and maintaining an electric potential between a cathode of the cathode chamber and an anode of an anode chamber with a potentiostat, wherein the cathode chamber and the anode chamber are separated by a semi-permeable membrane.
A well system includes a surface installation provided at a well surface location, a wellbore extending from the surface installation and providing an open hole section, a bore mapping device conveyable into the wellbore on a conveyance and including a bore surface mapping sensor operable to sense a surface of the open hole section as the bore mapping device traverses the wellbore, and an obstruction sensor arranged at a downhole end of the bore mapping device and operable to sense obstructions within the wellbore. A data acquisition system is in communication with the bore mapping device to receive data generated by the bore surface mapping sensor and the obstruction sensor and is operable to create a three-dimensional model of the open hole section of the wellbore.
A system (300)includes a pipe (100) for transporting one or more fluids, the pipe (100) including a scale deposit (108) formed on an inner circumferential surface thereof and defining a reduced diameter flow area (116) within the pipe (100), and a hybrid descaling tool (102) sized to be received within the pipe (100). The hybrid descaling tool (102) includes a laser head (104) comprising a hollow cylindrical body (202) with an internal, ring-shaped laser path (204), the laser head (104) operable to emit a ring-shaped laser beam (112) through the ring-shaped laser path (204), and an acid nozzle (107) protruding forward from the hollow cylindrical body (202) of the laser head (104) and into the reduced diameter flow area (116), the acid nozzle (107) including one or more acid outlets within the reduced diameter flow area (116).
A drilling fluid system includes: at least one microprocessor device; a container that defines an interior volume; a container inlet that provides access for entry of the at least one microprocessor device into the interior volume of the container; a container outlet that provides egress for passage of the at least one microprocessor device from the interior volume of the container into a drilling fluid conduit of the drilling system; and a dispenser apparatus configured to controllably release the at least one microprocessor device through the container outlet into the drilling fluid conduit of the drilling system. The at least one microprocessor device includes a power source and one or more sensors configured to generate sensor data indicating downhole conditions of a well and to wirelessly transmit the sensor data to a computer at a terranean surface.
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
17.
USE OF MINERAL INSULATED HEATERS TO APPLY EUTECTIC METALS TO REMEDIATE LOST CIRCULATION
A method for sealing a section of a well with a downhole plugging assembly using a basket (20) containing a mineral insulated heater (23) by running the downhole plugging assembly through the well and activating the mineral insulated heater (23). The heater (23) melts the eutectic metal alloy (26) to fill the downhole location with the melted alloy. The mineral insulated heater (23) is deactivated and the melted eutectic alloy cools to form a plug (32). A method for sealing a section of a well using a downhole plugging assembly containing a carrier fluid and a mineral insulated heater (23). The method includes running the downhole plugging assembly into the well, flowing the eutectic alloy suspended in the carrier fluid, connecting the electrical connection to a power source, and activating the mineral insulated heater (23) to melt the eutectic alloy (26) to fill the downhole location. The method includes allowing the eutectic alloy to cool to form a eutectic plug (32).
A system includes a pipe for transporting one or more fluids, the pipe including a scale deposit formed on an inner circumferential surface thereof and defining a reduced diameter flow area within the pipe, and a hybrid descaling tool sized to be received within the pipe. The hybrid descaling tool includes a laser head comprising a hollow cylindrical body with an internal, ring-shaped laser path, the laser head operable to emit a ring-shaped laser beam through the ring-shaped laser path, and an acid nozzle protruding forward from the hollow cylindrical body of the laser head and into the reduced diameter flow area, the acid nozzle including one or more acid outlets within the reduced diameter flow area.
C23G 3/04 - Apparatus for cleaning or pickling metallic material for cleaning pipes
B08B 5/04 - Cleaning by suction, with or without auxiliary action
B08B 9/043 - Cleaning the internal surfacesRemoval of blockages using cleaning devices introduced into and moved along the pipes moved by externally powered mechanical linkage, e.g. pushed or drawn through the pipes
B08B 15/04 - Preventing escape of dirt or fumes from the area where they are producedCollecting or removing dirt or fumes from that area from a small area, e.g. a tool
B23K 26/146 - Working by laser beam, e.g. welding, cutting or boring using a fluid stream, e.g. a jet of gas, in conjunction with the laser beamNozzles therefor the fluid stream containing a liquid
B23K 26/354 - Working by laser beam, e.g. welding, cutting or boring for surface treatment by melting
19.
INTEGRATED MODELING FOR SEISMIC SURVEY ACQUISITION PARAMETERIZATION
A computer-implemented method includes: accessing wireline data and vertical seismic profiling (VSP) data; correlating logged velocity from the wireline data with velocity data from the VSP data to calibrate the logged velocity; determining, based on, at least in part, the calibrated logged velocity, a range of incidence angles for acquiring seismic traces sufficient to map a formation depth at the geo-exploration site using pairs of acoustic emitter and acoustic receiver placed at a surface of the geo-exploration site; and determining a range of offsets between the acoustic emitter and the acoustic receiver of each pair so that the acoustic receiver can acquire seismic traces sufficient to map the formation depth at the geo-exploration site; and comparing the range of angles and the range of offsets with acquisition parameters of a planned seismic survey to determine whether the planned seismic survey can map as deep as the formation depth.
Slickwater fluids comprising aqueous formate fluids may promote underground carbon storage. In an aspect, slickwater fluids may be a slickwater fracturing fluid comprising: an aqueous formate fluid; proppant particulates; and optionally, one or more additives. Methods for use of a slickwater fluid as a slickwater fracturing fluid may comprise: contacting a slickwater fracturing fluid comprising an aqueous formate fluid; proppant particulates; and optionally, one or more additives; with a matrix of the subterranean formation above a fracture gradient pressure thereof to create or extend one or more fractures therein; and retaining at least a portion of the formate anions within the subterranean formation.
Microbial electrosynthesis (MES) may be used in converting carbon dioxide from a gas-oil separation plant (GOSP) to fixed carbon products. Example methods of MES may include: separating emitted carbon dioxide from an extracted gas-oil in a GOSP; dispersing the emitted carbon dioxide in a first portion of electrolyte solution in a cathode chamber of an electrolysis reactor; converting the emitted carbon dioxide to a fixed carbon product with a biocatalyst within the cathode chamber; and maintaining an electric potential between a cathode of the cathode chamber and an anode of an anode chamber with a potentiostat, wherein the cathode chamber and the anode chamber are separated by a semi-permeable membrane.
C12P 1/00 - Preparation of compounds or compositions, not provided for in groups , by using microorganisms or enzymesGeneral processes for the preparation of compounds or compositions by using microorganisms or enzymes
Slickwater fracturing fluids comprising one or more enzymes, one or more organisms capable of generating the one or more enzymes, or any combination thereof, may increase hydrocarbon production from a subterranean formation. In an aspect, slickwater fracturing fluids may comprise: an aqueous fluid, the enzymes, the organisms, or any combination thereof; proppant particulates; a friction reducer; and optionally, one or more additives. In an aspect, methods may comprise introducing the slickwater fracturing fluid into a subterranean formation; and contacting the slickwater fracturing fluid with a matrix of the subterranean formation. In an embodiment, methods may comprise introducing the slickwater fracturing fluid to the subterranean formation at a pressure and/or a flow rate sufficient to create and/or enlarge one or more fractures in the subterranean formation, and to force the slickwater fracturing fluid into the one or more fractures in the subterranean formation.
A metallic swarf sensor includes a housing configured to couple to a fluid conduit that includes a flowpath for a circulation of a wellbore fluid that includes metallic swarf; a magnetic tine assembly that includes a pair of magnetic tines that extend from the housing and connect through a magnetic flexure; a magnetic assembly at least partially enclosed within the housing and coupled to the magnetic tine assembly; and a piezoelectric actuator at least partially enclosed within the housing and coupled to the magnetic tine assembly. The magnetic assembly is configured to magnetize the magnetic tine assembly. The piezoelectric actuator is configured to resonate the magnetic tine assembly at a variable resonance frequency.
G01N 27/74 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables of fluids
Carbon dioxide may be stored in a subterranean formation. Methods of subterranean carbon dioxide storage may include: introducing, through an injection region of a unified wellbore to a subterranean formation, a carbonated aqueous fluid including carbon dioxide dispersed within an aqueous fluid, wherein the subterranean formation includes a basaltic formation; reacting the carbon dioxide or an ion thereof with the basaltic formation to form mineralized carbon and a produced aqueous fluid; flowing a mixture of the carbonated aqueous fluid and the produced aqueous fluid through a delivery region of the unified wellbore; depositing the mineralized carbon dioxide within the subterranean formation; and flowing the produced aqueous fluid from the subterranean formation through a production region of the unified wellbore, wherein the injection region and the production region are substantially vertical, and wherein the delivery region is substantially horizontal.
Methods may comprise contacting a sour gas with a treatment in a contactor, wherein the treatment comprises an amine and the sour gas comprises a hydrocarbon gas and an acid gas; absorbing at least a portion of the acid gas by the amine, thereby producing a first sweetened gas having an acid gas concentration lower than the sour gas, a first flare gas having an acid gas concentration higher than the first sweetened gas and lower than the sour gas, and a rich amine having an acid gas concentration higher than the first flare gas; flashing the rich amine to produce a utility gas; stripping at least another portion of the acid gas from the rich amine to form a lean amine and a second flare gas; and treating the combined flare gas in a gas treatment unit to form a second sweetened gas and a natural gas liquid.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 53/22 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by diffusion
C10L 3/10 - Working-up natural gas or synthetic natural gas
A method and a system are disclosed. The method includes including obtaining a first request to operate a first go-stop (G-S) smart valve in a well by a first user, wherein the first request is transmitted to a system manager in response to a user input of a first user credential to a first system device. The method further includes determining that the first user associated with the first user credential is authorized to operate the first G-S smart valve at the well and transmitting a command to the first G-S smart valve, wherein the command grants authorization to the first user to operate the first G-S smart valve. An operational status of the first G-S smart valve is indicated based on the determination and an access to the well is controlled based on the operational status of the first G-S smart valve.
A lost circulation material (LCM) composition comprising a spent drilling fluid and a chemical activator. The spent drilling fluid may comprise an aqueous solution, contaminants comprising heavy metals, salt, or both, and an alkaline nanosilica dispersion. The chemical activator may comprise a water soluble hydrolysable polyester. The spent drilling fluid may also have a pH and a gel pH, wherein the pH of the spent drilling fluid is greater than the gel pH.
A well system includes a surface installation provided at a well surface location, a wellbore extending from the surface installation and providing an open hole section, a bore mapping device conveyable into the wellbore on a conveyance and including a bore surface mapping sensor operable to sense a surface of the open hole section as the bore mapping device traverses the wellbore, and an obstruction sensor arranged at a downhole end of the bore mapping device and operable to sense obstructions within the wellbore. A data acquisition system is in communication with the bore mapping device to receive data generated by the bore surface mapping sensor and the obstruction sensor and is operable to create a three-dimensional model of the open hole section of the wellbore.
Various embodiments provide systems that include an optical cable deployable in a wellbore. At least a first plasmonic element and a second plasmonic element are associated with the optical fiber cable at a first location and a second location, respectively. The system further includes an optical interrogator system configured to: transmit an outgoing light into the optical fiber cable; and receive an incoming light corresponding to the outgoing light.
E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
G02B 6/30 - Optical coupling means for use between fibre and thin-film device
B82Y 20/00 - Nanooptics, e.g. quantum optics or photonic crystals
30.
A METHOD FOR CONSOLIDATING SAND IN HYDROCARBON RESERVOIRS
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Alarifi, Sulaiman A.
Murtaza, Mobeen
Baig, Abdul Rehman
Mahmoud, Mohamed A.
Kamal, Muhammad Shahzad
Alahmari, Manar M.
Humam, Abdulmohsen
Abstract
Preventing the flow of soil grains into oil and gas wells is highly desirable for the protection of hydrocarbon production. Geotechnical engineering solutions addressing this issue may utilize enzyme-induced precipitation methods to consolidate and increase shear strength. Methods may comprise: providing a mixture comprising urea, a urease enzyme, calcium chloride, magnesium chloride, and a cellulose; contacting at least a portion of the mixture with at least a portion of a subterranean formation; and forming a biomineral precipitate within the subterranean formation. The biomineral precipitate, comprised of a carbonate mineral and an evaporite mineral, may consolidate particles within the subterranean formation to form a consolidated body.
A downhole well tool includes a tubing including a circulation fluid pathway, a first packer, and a second packer positioned longitudinally apart from the first packer. The well tool includes a circulation sub connected to the tubing on a first longitudinal side of the second packer, the circulation sub including a first circulation port to fluidly couple the circulation fluid pathway to an annulus of the wellbore, and a plug seat positioned in the fluid circulation pathway. A second circulation port in the tubing is positioned longitudinally between the first packer and the second packer, and fluidly couples the circulation fluid pathway to the annulus of the wellbore between the first packer and the second packer. The second circulation port includes a frangible cover that plugs the second circulation port and ruptures in response to a burst pressure in the circulation fluid pathway.
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 33/138 - Plastering the borehole wallInjecting into the formation
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A microchip deployment system for a well includes a drilling fluid pump, a drilling fluid pipe extending from the drilling fluid pump into the well, and a microchip deployment mechanism provided on the drilling fluid pipe. The microchip deployment mechanism comprises a housing and a spherical valve. The housing has an input opening and an output opening. The spherical valve is rotatably arranged within the housing, and the spherical valve comprises a microchip pocket. The spherical valve is rotatable within the housing from a receiving position to a deploying position, wherein the microchip pocket is proximate to the input opening when in the receiving position, and wherein the microchip pocket is proximate to the output opening when in the deploying position.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A wellbore system includes coiled tubing extending into a wellbore from a surface location and a downhole tool coupled to a downhole end of the coiled tubing. A cable extends through the coiled tubing and is operably coupled to the downhole tool within the wellbore. An insert is disposed within the coiled tubing and engages the cable. The insert includes a plurality of elongated rods radially spaced around the cable and defining a longitudinal axis of the insert, and a plurality of retractable bars extending radially inwardly from the elongated rods. The retractable bars are biased radially inward to an extended position wherein the retractable bars flex the cable into an undulating configuration with respect to the longitudinal axis, and the retractable bars are responsive to an increased tension in the cable to move radially outward to a retracted configuration.
A composition for producing a glass fiber reinforced cement rebar, the composition comprising glass fiber; and a binder, the binder impregnates the glass fibers to hold the glass fibers together, where the binder comprises a cementitious component and a non-cement component, where the non-cement component comprises graphene oxide.
A conformance control method includes identifying a target location of a wellbore formed from a terranean surface to two subterranean formations that include a high permeability formation having a first permeability and a low permeability formation having a second permeability that is equal or less than one-third of the first permeability. The method includes forming a first plurality of tunnels in the high permeability formation from the wellbore; injecting, into the high permeability formation and the low permeability formation, a chemical fluid from the wellbore through the first plurality of tunnels; expanding a sweep area of the injected chemical fluid by injecting the chemical fluid into the high permeability formation through the first plurality of tunnels; forming a second plurality of tunnels in the low permeability formation from the wellbore; and increasing a contact area of an injection fluid in the low permeability formation with the second plurality of tunnels.
E21B 7/18 - Drilling by liquid or gas jets, with or without entrained pellets
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
36.
Method of enhancing carbon dioxide storage capacity in salt caverns
The present disclosure is directed toward a method for storing carbon dioxide. The method for storing carbon dioxide comprises several steps. A dissolving fluid comprising water is injected into a salt formation to produce a brine and a salt cavern within the salt formation. The brine is then removed from the salt cavern. A sorbent is then placed within the salt cavern before carbon dioxide is injected into the salt cavern.
A system includes an automatic computer-controlled management system and a compressed air system. The system includes a first standby compression generator pneumatically coupled to the compressed air system and coupled to the automatic computer-controlled management system. The system includes a second standby compression generator of a set of standby compression generators pneumatically coupled to the compressed air system and coupled to the automatic computer-controlled management system. The first standby compression generator is configured to transmit first standby compression generator data to the automatic computer-controlled management system and the second standby compression generator is configured to transmit second standby compression generator data to the automatic computer-controlled management system.
G05B 19/416 - Numerical control [NC], i.e. automatically operating machines, in particular machine tools, e.g. in a manufacturing environment, so as to execute positioning, movement or co-ordinated operations by means of programme data in numerical form characterised by control of velocity, acceleration or deceleration
A system for conditioning a feed stream that may include a feed inlet, a cycloid pipe, a tangential inlet pipe, and a main pipe, wherein the main pipe and the cycloid pipe may be fluidly connected. The feed inlet may be configured to receive a feed stream including multiphase fluids.
A method for determining an anomaly in a gas-lift system. The method includes obtaining gas-lift data from a gas-lift system and associated well, where the gas-lift system injects a gas into a fluid mixture of the well. The method further includes obtaining a set of operation parameters including an injected gas rate and an injected gas pressure. The method further includes determining, with a first machine learned model and a second machine learned model, a first and second anomaly metric each indicative of an anomaly in the gas-lift system or a flow of a production fluid from the well, respectively, based on the gas-lift data. The method further includes forming an aggregate anomaly prediction from the first anomaly metric and the second anomaly metric and adjusting, with a controller, the set of operation parameters based on, at least, the aggregate anomaly prediction.
A ceiling system configured such that when a runner of a first panel assembly and a runner of a second panel assembly are each slidably disposed within a channel of a rail and the rail is attached to the support member, the first panel assembly and the second panel assembly are independently suspended by respective wires from the rail. Sliding the runner of the first panel assembly towards the runner of the second panel assembly translates the respective panels of the panel assemblies towards each other, thereby positioning an edge of the panel of the first panel assembly adjacent an edge of the panel of the second panel assembly for attachment, such that the second planar surface of the panel of the first planar assembly and the second planar surface of the panel of the second planar assembly at least partially define an interior surface of the ceiling.
E04B 9/22 - Connection of slabs, sheets or the like to the supporting construction
E04B 9/04 - CeilingsConstruction of ceilings, e.g. false ceilingsCeiling construction with regard to insulation comprising slabs, sheets or the like
E04B 9/06 - CeilingsConstruction of ceilings, e.g. false ceilingsCeiling construction with regard to insulation characterised by constructional features of the supporting construction
E04B 9/30 - CeilingsConstruction of ceilings, e.g. false ceilingsCeiling construction with regard to insulation characterised by edge details of the ceiling, e.g. securing to an adjacent wall
Systems and methods include obtaining well log data and core sample data of a subsurface formation; generating, based on the well log data and the core sample data, an unconfined compressive strength log for the subsurface formation; using an unsupervised machine learning model to form rock type clusters based on the unconfined compressive strength log and the well log data; forming a training dataset including the well log data, the training dataset labeled based on the rock type clusters; training a supervised machine learning model using the training dataset. While drilling a well in the subsurface formation, logging-while-drilling data is obtained from drilling equipment used to drill the well; and rock types in the subsurface formation are determined using the supervised machine learning model and the logging-while-drilling data.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods 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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 45/00 - Measuring the drilling time or rate of penetration
A composition for producing a glass fiber reinforced cement rebar, the composition comprising glass fiber; and a binder, the binder impregnates the glass fibers to hold the glass fibers together, where the binder comprises a cementitious component and a non-cement component, where the non-cement component comprises graphene oxide.
C04B 20/00 - Use of materials as fillers for mortars, concrete or artificial stone according to more than one of groups and characterised by shape or grain distributionTreatment of materials according to more than one of the groups specially adapted to enhance their filling properties in mortars, concrete or artificial stoneExpanding or defibrillating materials
C04B 22/00 - Use of inorganic materials as active ingredients for mortars, concrete or artificial stone, e.g. accelerators
C04B 24/26 - Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
C04B 40/00 - Processes, in general, for influencing or modifying the properties of mortars, concrete or artificial stone compositions, e.g. their setting or hardening ability
C04B 40/02 - Selection of the hardening environment
C04B 111/00 - Function, property or use of the mortars, concrete or artificial stone
C04B 111/10 - Compositions characterised by the absence of a specified material
A downhole well tool includes a tubing including a circulation fluid pathway, a first packer, and a second packer positioned longitudinally apart from the first packer. The well tool includes a circulation sub connected to the tubing on a first longitudinal side of the second packer, the circulation sub including a first circulation port to fluidly couple the circulation fluid pathway to an annulus of the wellbore, and a plug seat positioned in the fluid circulation pathway. A second circulation port in the tubing is positioned longitudinally between the first packer and the second packer, and fluidly couples the circulation fluid pathway to the annulus of the wellbore between the first packer and the second packer. The second circulation port includes a frangible cover that plugs the second circulation port and ruptures in response to a burst pressure in the circulation fluid pathway.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
44.
THERMALLY ACTIVATED AUTONOMOUS INFLOW CONTROL DEVICE
A system includes an inflow control device (ICD) that modulates an inflow of hydrocarbons within the wellbore and a sleeve. The sleeve is slidably disposed adjacent to the ICD and connected to an elastic material with a thermal memory. The elastic material changes its shape based on a change in temperature. Based on (i) the elastic material being in a compressed state below a temperature threshold and (ii) the sleeve being at a first position relative to the ICD, the elastic material allows a fluid communication between the ICD and outside the wellbore. Based on (i) the elastic material being in a stretched state at or above the temperature threshold and (ii) the sleeve being at a second position relative to the ICD, the elastic material blocks the fluid communication between the ICD and outside the wellbore.
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
45.
DETERMINING HYDRAULIC FRACTURING TREATMENT METHODS FOR WELLS IN CARBONATE RESERVOIRS
Techniques for stimulating a formation surrounding a wellbore include determining a rock type of the formation along the well trajectory in landing zone in terms of measured depth. A depth-specific acid fracture conductivity parameter of the formation and a depth-specific fracture conductivity declining parameter of the formation are determined. One or more depth intervals requiring fracturing are determined based on the rock type of the formation, the acid fracture conductivity parameter of the formation, and the fracture conductivity declining parameter of the formation. A fracturing method is determined for each depth interval of the one or more depth intervals based on the acid fracture conductivity parameter of the formation and the fracture conductivity declining parameter of the formation. A corresponding pump schedule of the fracturing method is determined, and a fluid of the pump schedule is pumped into the wellbore to fracture or stimulate the formation.
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods 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 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
A pump cleaning assembly includes a ring assembly configured to be mounted at a seal nose coaxial with a shaft center-line of a pump shaft of a pump; a plurality of spring-loaded nozzles positioned in the ring assembly and configured to spray a pressurized liquid along the pump shaft within a pump housing of the pump; and a liquid pump fluidly coupled to the plurality of spring-loaded nozzles through a tubing assembly.
A method for determining and performing an optimum well intervention sequence on a well operation described by an operating condition. The method includes obtaining a first well data for the well operation and determining, using an artificial intelligence (AI) model with the first well data as input, a first operating condition for the well operation. The method further includes obtaining a plurality of well interventions that can be performed on the well operation, determining, using a reinforcement learning (RL) policy, an optimum well intervention sequence that optimizes a performance of the well operation and performing the optimum well intervention sequence on the well operation.
A method of recovering oil from a formation includes providing carbonated water in a lower zone of the formation, releasing carbon dioxide gas from the carbonated water to produce released carbon dioxide gas, causing the released carbon dioxide gas to contact oil in an upper zone of the formation to increase a mobility of the oil, and recovering the oil from the formation.
A method, system, and non-transitory computer readable media for landcover map generation of an environment. The operations include receiving an image captured at an aerial position above the environment, obtaining coordinate information of the environment corresponding to pixels of the image, and determining coordinate measures. The operations include generating image patches, each image patch representing a portion of the pixels and applying image processing techniques to adjust pixel values of a respective image patch. The operations include providing the adjusted image patches to a generative adversarial network (GAN) and generating landcover map patches from the adjusted image patches. The GAN includes a generator network trained to generate training landcover map patches from an image patch and a discriminator network trained to classify training landcover map patches from the generator network. The operations include generating a landcover map from the landcover map patches and providing the landcover map for output.
G06T 7/579 - Depth or shape recovery from multiple images from motion
G06T 7/593 - Depth or shape recovery from multiple images from stereo images
G06T 17/20 - Wire-frame description, e.g. polygonalisation or tessellation
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
G06V 10/98 - Detection or correction of errors, e.g. by rescanning the pattern or by human interventionEvaluation of the quality of the acquired patterns
G06V 20/70 - Labelling scene content, e.g. deriving syntactic or semantic representations
50.
FLUID FLOW VELOCITY MEASUREMENT VIA THERMAL CONDUCTION
A fluid velocity sensor can include a thermally conductive body comprising a first temperature sensor, a second temperature sensor, and a third temperature sensor. A heating element is secured within the fluid velocity sensor to heat the thermally conductive body. The first temperature sensor, the second temperature sensor, and the third temperature sensor each reside within the thermally conductive body at different radial distances from the heating element. A flowrate of a fluid in contact with the fluid velocity sensor is determined based on a comparison between the internal temperatures measured by each of the first, second, and third temperature sensors.
King Fahd University of Petroleum and Minerals (Saudi Arabia)
Inventor
Akah, Aaron Chi
Al-Ghrami, Musaed Salem
Aitani, Abdullah Mohammed
Qureshi, Ziyauddin
Siddiqui, Mohammed Abdul Bari
Abstract
A process for upgrading a hydrocarbon feed comprises contacting the hydrocarbon feed with steam in the presence of a cracking catalyst composition at reaction conditions sufficient to cause at least a portion of hydrocarbons in the hydrocarbon feed to undergo one or more cracking reactions to produce a steam catalytic cracking effluent comprising light olefins, light aromatic compounds, or both, where the cracking catalyst composition comprises a cracking additive comprising metal species impregnated on a ZSM-5 zeolite, where the metal species comprises a metal selected from the group consisting of chromium, vanadium, iron, platinum, molybdenum, cerium, and nickel.
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Da, Chang
Zhang, Xuan
Han, Ming
Abstract
A method of preparing a polymeric surfactant includes dissolving a sulfonic acid monomer in an aqueous fluid to form a sulfonic acid solution, adding an acrylic monomer and a surfactant monomer to the sulfonic acid solution to form a reactive mixture, adding one or more initiators to the reactive mixture to initiate a reaction in the reactive mixture, and allowing the reactive mixture to react, thereby forming the polymeric surfactant. A method of enhancing oil recovery in a reservoir includes preparing a polymeric surfactant formulation that comprises a polymeric surfactant and a treatment fluid, injecting the polymeric surfactant formulation into an injection well of the reservoir, contacting one or more hydrocarbons present in the reservoir with the polymeric surfactant formulation, thereby forming a hydrocarbon mixture, and extracting the hydrocarbon mixture from a production well of the reservoir.
C09K 8/588 - 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 polymers
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
C08F 220/58 - Amides containing oxygen in addition to the carbonamido oxygen
A process for a low-carbon footprint hydrogen production includes producing natural gas from a reservoir. The natural gas is sweetened to produce a sweet natural gas and an acid gas stream. The sweet natural gas is fed to a methane purification unit (31) and purified to remove residual hydrogen sulfide. The acid gas stream is fed to a carbon dioxide feed purification unit (32) and the carbon dioxide in the acid gas stream is purified. The purified methane (13), the purified carbon dioxide (15) and steam (16) are fed as reactants to a tri-reforming reactor (33), containing a tri-reforming catalyst, to produce a reaction effluent comprising hydrogen and carbon monoxide. An effluent is recovered from the tri-reforming reactor (33), which is then separated to recover a raw hydrogen stream and a raw carbon monoxide stream. The raw hydrogen stream is purified to recover a purified hydrogen stream, which is liquified to recover a liquid hydrogen product.
C01B 3/38 - 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 by reaction of hydrocarbons with gasifying agents using catalysts
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
54.
Methods and systems to stimulate rock surrounding a wellbore using ultrasound at a preferred frequency
Methods and systems are disclosed. The method may include obtaining, using a rock characterization system, a plurality of characteristics for a rock penetrated by a wellbore, and determining, using a model of poroelasticity and the plurality of characteristics, a preferred ultrasonic frequency at which to insonify the rock. The method may further include deploying an ultrasonic stimulation tool in the wellbore, where the ultrasonic stimulation tool comprises at least one ultrasonic transducer, and activating the ultrasonic stimulation tool at the preferred ultrasonic frequency.
An engine includes a first crankshaft and a second crankshaft, pistons, piston rods, cylinders, combustion chambers, and fuel injectors. The crankshafts each extend in a horizontal plane and form a first and second rotating power output shaft of the engine. The combustion chambers form containment boundaries for combustion reactions of an air-fuel mixture formed in the cylinders with fuel provided by the fuel injectors. The piston rods connect the pistons to the first or the second crankshaft. The pistons are disposed in the cylinders, and the planar surface of the piston head of each piston distributes forces from an associated combustion reaction to a corresponding piston rod. The piston heads are disposed at an angle between 7 and 15 degrees in the first bank of cylinders and −7 and −15 degrees in the second bank of cylinders relative to a vertical plane.
F01B 1/04 - Reciprocating-piston machines or engines characterised by number or relative disposition of cylinders or by being built-up from separate cylinder-crankcase elements with cylinders in V-arrangement
F01B 9/02 - Reciprocating-piston machines or engines characterised by connections between pistons and main shafts, not specific to groups with crankshaft
F02B 75/22 - Multi-cylinder engines with cylinders in V-, fan-, or star-arrangement
A pump shaft stand for supporting a pump shaft while a pump is being serviced. The pump shaft stand includes a frame, a receptacle coupled with the frame, and an elevator for positioning the receptacle. The elevator is adjustable to place the receptacle in a designated position, so that when an end of the pump shaft is supported by the receptacle, the pump shaft does not move by an amount that can damage the shaft or associated components of the pump.
Systems, methods, and apparatus for characterizing reservoirs are discussed. As an example, a method for characterizing a reservoir is discussed that includes determining a ki parameter, a αE parameter, and a αP parameter based at least in part on the at least four pairs of effective stress and permeability; and predicting a hydrocarbon production rate from reservoir represented by the sample rock based at least in part on the ki parameter, the αE parameter, and the αP parameter.
Data processing systems and processing methods are configured to process geoscience data for a set of different data domains. The data processing systems described herein are configured to unify data sources from the set of different domains to process data in the context of each of the different domains of the set. The data processing system can use data, such as training data or trained model weightings, that are generated when performing a processing workflow in a first domain for updating how a second processing workflow is performed for a second, different domain, and vice versa. The data processing system can improve both processing workflows based on the contexts of the other workflow being performed.
Various systems and methods are discussed for characterizing well properties. As one of many non-limiting examples, a well property system is discussed that includes a sensor set, a logging system, an archive conversion system, and a well property prediction system. Each of the aforementioned components and systems may be configured to sense and/or operate on pressure, volume, and temperature data from at least one location at a well site.
King Abdullah University of Science and Technology (Saudi Arabia)
Inventor
Alshareef, Husam Niman
Zhao, Zhiming
El-Demellawi, Jehad Khaled
Abstract
An electrochemical cell for a rechargeable battery, where the electrochemical cell includes: an anode including lithium (Li); an anode current collector connected to the anode; a cathode; a cathode current collector connected to the cathode; a separator between the anode and the cathode; and a liquid electrolyte including: a solvent, a Li salt dissolved in the solvent, and a polyvalent metal salt dissolved in the solvent.
H01M 10/0568 - Liquid materials characterised by the solutes
H01M 4/131 - Electrodes based on mixed oxides or hydroxides, or on mixtures of oxides or hydroxides, e.g. LiCoOx
H01M 4/505 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides of manganese of mixed oxides or hydroxides containing manganese for inserting or intercalating light metals, e.g. LiMn2O4 or LiMn2OxFy
H01M 4/525 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides of nickel, cobalt or iron of mixed oxides or hydroxides containing iron, cobalt or nickel for inserting or intercalating light metals, e.g. LiNiO2, LiCoO2 or LiCoOxFy
H01M 10/0569 - Liquid materials characterised by the solvents
61.
CATALYST PELLETS THAT INCLUDE POLYGONAL PRISMATIC BODIES, PACKED BED REACTORS INCLUDING THE SAME, AND METHODS FOR HYDROPROCESSING UTILIZING THE SAME
Embodiments herein are directed to a catalyst pellet including a substantially regular polygonal prismatic body including a first polygonal surface, a second polygonal surface opposite the first polygonal surface, and n faces each extending in a length dimension from the first polygonal surface to the second polygonal surface, where n is equal to an integer from 5 to 20. The catalyst pellet includes n apertures extending from the first polygonal surface to the second polygonal surface. Each aperture has a substantially cylindrical shape and is positioned such that it is oriented towards a corner of the first polygonal surface and the second polygonal surface. Further embodiments are directed to a packed bed reactor including a reactor vessel and a packed catalyst bed including at least one catalyst pellet described herein. Further embodiments are directed to a method for hydroprocessing a hydrocarbon feed including passing the hydrocarbon feed into a reactor vessel, such that the hydrocarbon feed contacts a packed catalyst bed including at least one catalyst pellet described herein to form a product composition and passing the product composition out of the reactor vessel.
B01J 35/50 - Catalysts, in general, characterised by their form or physical properties characterised by their shape or configuration
B01J 8/02 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with stationary particles, e.g. in fixed beds
B01J 29/04 - Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites, pillared clays
B01J 35/40 - Catalysts, in general, characterised by their form or physical properties characterised by dimensions, e.g. grain size
C10G 49/04 - Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups , , , , or characterised by the catalyst used containing nickel, cobalt, chromium, molybdenum, or tungsten metals, or compounds thereof
62.
SYSTEM AND METHOD CONFIGURED TO PERFORM POWERSHELL MONITORING OF COMMUNICATIONS TO A COMPUTER-BASED SYSTEM USING KEYWORDS
A system and method monitor a communication directed to a computer-based system. A memory stores predetermined keywords and predetermined scores each corresponding to a predetermined keyword. A communications monitoring module monitors data string corresponding to the communications and detects a first keyword in the data string. An event code generating module generates an event code corresponding to the data string. A management module detects the generated event code. A keyword matching module searches the predetermined keywords for the detected first keyword and matches the detected first keyword with the generated event code. A score generating module generates a determined score from the detected first keyword and from the predetermined scores. A message generating module compares the determined score with a predetermined threshold and generates a message based on the comparison. The output device outputs the message corresponding to the communication. The method implements the system.
Korea Advanced Institute of Science and Technology (KAIST) (Republic of Korea)
Inventor
Imran, Hasan
Aldawsari, Yasmeen
Al Hunaidy, Ali Shakir
Roh, Kosan
Lee, Jay H.
Chung, Wonsuk
Abstract
A system and method for producing ethanol, including dry reforming of methane with carbon dioxide to produce syngas, cryogenically separating carbon monoxide from syngas giving a first stream including primarily carbon monoxide and hydrogen. The method includes synthesizing methanol from the second stream via hydrogenation of carbon monoxide in the second stream and finally synthesizing ethanol via methanol homologation including the first stream of cryogenically separated carbon monoxide and a hydrogen stream.
C07C 29/32 - Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring increasing the number of carbon atoms by reactions without formation of hydroxy groups
B01D 53/00 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols
C01B 3/34 - 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 by reaction of hydrocarbons with gasifying agents
64.
LASER DESCALING SYSTEM WITH MAGNETIC ROBOTIC CONTROLS
A laser descaling tool includes a laser head formed of a magnetic or ferromagnetic material, a flexible laser arm defining first and second ends, the flexible laser arm coupled to the laser head at the first end and responsive to modification of a magnetic field to reorient the laser head, a support arm coupled to the flexible laser arm at the second end, a fiber optic cable extending through the flexible laser arm and the support arm to a control location, a laser source disposed at the control location and optically coupled to the laser head through the fiber optic cable, and a vacuum mounted at the second end of the laser arm and operable to collect debris from a scale deposit within an interior of a pipe.
B08B 7/00 - Cleaning by methods not provided for in a single other subclass or a single group in this subclass
B08B 5/02 - Cleaning by the force of jets, e.g. blowing-out cavities
B08B 5/04 - Cleaning by suction, with or without auxiliary action
B08B 9/043 - Cleaning the internal surfacesRemoval of blockages using cleaning devices introduced into and moved along the pipes moved by externally powered mechanical linkage, e.g. pushed or drawn through the pipes
65.
COMPACT VENTURI WITH EMBEDDED DUAL MUTUALLY ORTHOGONAL RESONATOR (DMOR) SENSORS TO MEASURE MULTIPHASE FLOW RATES
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
Inventor
Arsalan, Muhammad
Karimi, Muhammad Akram
Akhter, Zubair
Shamim, Atif
Abstract
A Waventuri flowmeter includes a Venturi flowmeter with a multiphase fraction measurement device incorporated therein. The Waventuri flowmeter includes an inlet for receiving a wellbore fluid into the flowmeter, the inlet defining an inlet diameter and an outlet for discharging the wellbore fluid from the flowmeter, the outlet defining an outlet diameter. A flow path extends between the inlet and the outlet and includes a converging section downstream of the inlet and a diverging section downstream of the converging section. At least one sensor is operable to detect a parameter indicative of pressures of the wellbore fluid at the inlet and a throat between the converging and diverging sections. First and second permittivity sensors extend axially along the diverging and converging sections, respectively. The first and second permittivity sensors are operable to measure parameters indicative of multiphase volume fractions of the wellbore fluid within the diverging and converging sections.
A method for determining a pore throat size distribution in a rock sample includes saturating the rock sample with a fluid to a maximum saturation, acquiring a first set of nuclear magnetic resonance (NMR) measurements of the rock sample, generating based on a first T2 distribution of the first set of NMR measurements a first saturation profile and a first set of slice measurements, obtaining a peak T2 measurement and an average pore throat size measurement by conducting a subsequent NMR measurement procedure, repeating obtaining a peak T2 measurement until the rock sample has a minimum saturation, obtaining a fit function by fitting the average pore throat size measurements to the peak T2 measurements, and generating a pore throat size distribution from the first T2 distribution. A computer system for determining a pore size distribution in a rock sample includes a processor and a memory coupled to the processor.
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
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
Systems and methods are disclosed. The method includes obtaining a reservoir model and a production scenario. The method also includes determining a first set of parameters for a first time from the reservoir model and the production scenario, predicting, using the first set of parameters, a second set of parameters at a second, later, time, including primary variables used to determine values for a mass, a flux and a well term. Predicting includes, iteratively until a stopping criterion is satisfied, for each computational cells in the reservoir model, using the first set of parameters to determine a primary variable update and a residual, determining an updated flux and well term, predicting the second set of parameters from the updated flux and well term, assigning the second set of parameters to the first set of parameters, and determining a predicted location of unproduced hydrocarbons from the second set of parameters.
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
68.
Evaluating Biological Materials at Reservoir Conditions
Systems and methods for evaluating biological materials at reservoir conditions include a reactor housing and a plurality of test columns having source rock sample holders. The plurality of test columns is disposed within the reactor housing. A pump is fluidly coupled to the reactor housing. A heating element is coupled to the reactor housing; and one or more sensors are coupled to the test columns configured to measure properties of biomaterials or biochemical interactions in the rock samples.
An arrangement of cancellation electromagnets control magnetic adhesion of a wheel to a surface. The wheel has an inner annular disc composed of a non-magnetic material with apertures which retain electromagnets and permanent magnets, and an outer annular disc composed of a ferromagnetic material which is disposed on a side of the inner annular disc, with a non-magnetic isolator ring having curves extending in a serpentine manner. In one embodiment, the curves isolate the electromagnets from the permanent magnets. In another embodiment, the outer annular disc is rotated relative to the inner annular disc to dispose the curves of the serpentine isolator ring in a second position to allow magnetic interaction between the electromagnets and the permanent magnets to generate a second magnetic flux between the permanent magnets and the ferromagnetic surface which decreases adhesion of the wheel to the ferromagnetic surface. A method implements the system.
Embodiments herein are directed to a catalyst pellet including a substantially regular polygonal prismatic body including a first polygonal surface, a second polygonal surface opposite the first polygonal surface, and n faces each extending in a length dimension from the first polygonal surface to the second polygonal surface, where n is equal to an integer from 5 to 20. The catalyst pellet includes n apertures extending from the first polygonal surface to the second polygonal surface. Each aperture has a substantially cylindrical shape and is positioned such that it is oriented towards a corner of the first polygonal surface and the second polygonal surface. Further embodiments are directed to a packed bed reactor including a reactor vessel and a packed catalyst bed including at least one catalyst pellet described herein. Further embodiments are directed to a method for hydroprocessing a hydrocarbon feed including passing the hydrocarbon feed into a reactor vessel, such that the hydrocarbon feed contacts a packed catalyst bed including at least one catalyst pellet described herein to form a product composition and passing the product composition out of the reactor vessel.
Disclosed are methods, systems, and computer-readable medium to perform operations including: obtaining sensor data from at least one sensor attached to a surface of a drill bit; providing the sensor data from the at least one sensor to one or more machine learning models, wherein the one or more machine learning models are trained using a library of (i) sensor signatures and (ii) geological formations to output one or more drilling parameters; and adjusting one or more parameters of an operation performed by a drill controlling the drill bit based on the one or more drilling parameters output by one or more machine learning models.
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
72.
COMPACT VENTURI WITH EMBEDDED DUAL MUTUALLY ORTHOGONAL RESONATOR (DMOR) SENSORS TO MEASURE MULTIPHASE FLOW RATES
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
SAUDIA ARABIAN OIL COMPANY (Saudi Arabia)
Inventor
Arsalan, Muhammad
Karimi, Muhammad Akram
Akhter, Zubair
Shamim, Atif
Abstract
A Waventuri flowmeter includes a Venturi flowmeter with a multiphase fraction measurement device incorporated therein. The Waventuri flowmeter includes an inlet for receiving a wellbore fluid into the flowmeter, the inlet defining an inlet diameter and an outlet for discharging the wellbore fluid from the flowmeter, the outlet defining an outlet diameter. A flow path extends between the inlet and the outlet and includes a converging section downstream of the inlet and a diverging section downstream of the converging section. At least one sensor is operable to detect a parameter indicative of pressures of the wellbore fluid at the inlet and a throat between the converging and diverging sections. First and second permittivity sensors extend axially along the diverging and converging sections, respectively. The first and second permittivity sensors are operable to measure parameters indicative of multiphase volume fractions of the wellbore fluid within the diverging and converging sections.
33-containing gas such that the carbon microparticles have a hydrophilic surface (205), and grinding the carbon microparticles to provide carbon nanoparticles (106). The carbon nanoparticles (106) have a hydrophilic surface (205) and a hydrophobic surface (207). A method of enhanced oil recovery is also described.
C09K 8/03 - Specific additives for general use in well-drilling compositions
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
74.
EFFICIENT SURFACE FUNCTIONALIZATION FOR SCALE-UP SYNTHESIS OF JANUS CARBON NANOFLUIDS
A method of preparing an enhanced oil recovery composition is provided. The method includes carbonizing (200) a waste carbon material (202) to provide carbon microparticles (208) having a hydrophobic surface (404), functionalizing (300) the carbon microparticles (208) with an alkaline solution (302) such that the carbon microparticles (208) have a hydrophilic surface (306), and grinding (400) the carbon microparticles (208) to provide carbon nanoparticles (406). The carbon nanoparticles (406) have a hydrophilic surface (306) and a hydrophobic surface (404). The method may further include mixing the carbon nanoparticles with an aqueous based fluid to provide an enhanced oil recovery fluid.
C09K 8/03 - Specific additives for general use in well-drilling compositions
C01B 32/05 - Preparation or purification of carbon not covered by groups , , ,
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
75.
SULFONATION METHOD FOR EFFICIENT SCALE-UP SYNTHESIS OF JANUS CARBON NANOMATERIALS FROM BIOMASS WASTE
333- containing gas and including a hydrophilic and hydrophobic surface into a hydrocarbon-bearing formation. The method includes displacing hydrocarbons from the hydrocarbon-bearing formation and recovering the hydrocarbons.
C09K 8/03 - Specific additives for general use in well-drilling compositions
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
76.
CONDITIONING A TUBING HEAD BACK PRESSURE VALVE RECEPTACLE
A tool is used for installing and/or operating a back pressure valve mounted in a profile formed in an upper end of a tubing hanger. The tool is also used to remove deposits from the profile by attaching a conditioning module to the tool, and engaging the profile with the module. The module includes a body having a cylindrical mid-portion and frusto-conical upper and lower portions. Brush assemblies circumscribe the body at different elevations along the mid-portion, which remove the deposits on the profile when the module is simultaneously rotated and pressed against the profile. The brush assemblies are made up of sections that each have a base secured to the body and brush elements projecting radially outward from the body. After the deposits are removed, the back pressure valve is installed using the tool.
A method includes providing an electrical submersible pump assembly (ESP) with a pump, an intake, a gel canister, a protector, and a motor disposed in a casing. The method includes providing fluid communication between a production tubing and the ESP, the production tubing delivering well fluid containing solid particles and liquids from the ESP into a wellhead assembly through an inner bore of the production tubing. The method includes locating a pressure release conduit configured in a closed state, between a canister exterior in a hydraulic communication with a canister inner chamber of the gel canister and the inner bore. The closed state prevents the hydraulic communication between the canister inner chamber and the inner bore. The method includes delivering a canister contents to the well fluid.
Systems and methods are disclosed relating to geological model upscaling. Training data representative of previously captured, generated, and/or recorded detailed geological data for one or more subsurfaces of a planet can be received. A diffusion model can be trained based on the training data to optimize parameters of the diffusion model. Detailed geological data for a respective subsurface of the planet can be received, and the detailed geological data can be upscaled using the trained diffusion model. Upscaled geological data can be generated based on the upscaling. In some examples, an upscaled geological model representative of the respective subsurface can be generated based on the upscaled geological data. The upscaled geological model can be simulated to model a behavior of the respective subsurface.
Disclosed are methods, systems, and computer-readable medium to perform operations including: obtaining sensor data from at least one sensor attached to a surface of a drill bit; providing the sensor data from the at least one sensor to one or more machine learning models, wherein the one or more machine learning models are trained using a library of (i) sensor signatures and (ii) geological formations to output one or more drilling parameters; and adjusting one or more parameters of an operation performed by a drill controlling the drill bit based on the one or more drilling parameters output by one or more machine learning models.
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
Described is a system for targeted waterflooding in an oil field. The system includes a mobile reverse osmosis unit connected with source water. The mobile reverse osmosis unit generates low salinity fresh water from the source water. An injection manifold is connected with the mobile reverse osmosis unit. The injection manifold distributes the low salinity fresh water into injection wells within the oil field. The low salinity fresh water is stored underground prior to its use in production wells.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
Inventor
Alshareef, Husam Niman
Zhao, Zhiming
El-Demellawi, Jehad Khaled
Abstract
An electrochemical cell for a rechargeable battery, where the electrochemical cell includes: an anode including lithium (Li); an anode current collector connected to the anode; a cathode; a cathode current collector connected to the cathode; a separator between the anode and the cathode; and a liquid electrolyte including: a solvent, a Li salt dissolved in the solvent, and a polyvalent metal salt dissolved in the solvent.
H01M 4/525 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides of nickel, cobalt or iron of mixed oxides or hydroxides containing iron, cobalt or nickel for inserting or intercalating light metals, e.g. LiNiO2, LiCoO2 or LiCoOxFy
H01M 4/38 - Selection of substances as active materials, active masses, active liquids of elements or alloys
H01M 4/131 - Electrodes based on mixed oxides or hydroxides, or on mixtures of oxides or hydroxides, e.g. LiCoOx
H01M 4/134 - Electrodes based on metals, Si or alloys
H01M 10/0561 - Accumulators with non-aqueous electrolyte characterised by the materials used as electrolytes, e.g. mixed inorganic/organic electrolytes the electrolyte being constituted of inorganic materials only
H01M 10/056 - Accumulators with non-aqueous electrolyte characterised by the materials used as electrolytes, e.g. mixed inorganic/organic electrolytes
A laser descaling tool (100) includes a laser head (102) formed of a magnetic or ferromagnetic material, a flexible laser arm (110) defining first and second ends, the flexible laser arm coupled to the laser head at the first end and responsive to modification of a magnetic field to reorient the laser head, a support arm (118) coupled to the flexible laser arm at the second end, a fiber optic cable (120) extending through the flexible laser arm and the support arm to a control location (308), a laser source (310) disposed at the control location and optically coupled to the laser head through the fiber optic cable, and a vacuum (114) mounted at the second end of the laser arm and operable to collect debris from a scale deposit within an interior of a pipe (300). Also disclosed is a system comprising a laser descaling tool and one or more crawlers (200) movable on the outer circumferential surface of the pipe and one or more magnetic field generators (210) carried by the crawlers operable to produce said magnetic field for reorienting the laser head.
A method (700) includes providing (710) an electrical submersible pump assembly, ESP (310) with a pump, an intake, a gel canister (314), a protector, and a motor disposed in a casing. The method includes providing (720) fluid communication between a production tubing and the ESP, the production tubing delivering well fluid containing solid particles and liquids from the ESP into a wellhead assembly through an inner bore of the production tubing. The method includes locating (730) a pressure release conduit configured in a closed state, between a canister exterior in a hydraulic communication with a canister inner chamber of the gel canister and the inner bore. The closed state prevents the hydraulic communication between the canister inner chamber and the inner bore. The method includes delivering (740) a canister contents to the well fluid.
A cuttings collection system (200) includes a drill bit (112) at the end of a toolstring (104), a stabilizer (202) connected to the drill bit (112), a cuttings catcher (206) arranged around the stabilizer (202) with apertures having a size less than an average size of cuttings generated by the drill bit (112) and retractability, and sensors (204) installed in a body of the stabilizer (202). A cuttings catcher (206) includes a housing (302) with recesses (306) and a retractable mesh (308) installed in each of the recesses (306). A method of operating an at-bit cuttings catcher system (200) includes providing a toolstring (104) with a drill bit (112), a stabilizer (202), a cuttings catcher (206), and a measurement-while-drilling tool (208), where the cuttings catcher (206) includes a housing (302) with recesses (306) and a mesh (308) installed in the recesses (306), drilling a formation (116) using the drill bit (112), producing cuttings of the formation (116), extending the mesh (308) from the housing (302) of the cuttings catcher (206), catching cuttings in the cuttings catcher (206), and analyzing the cuttings using sensors (204).
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
85.
METHOD AND SYSTEM TO ACCELERATE THE NONLINEAR SOLUTION IN NUMERICAL RESERVOIR SIMULATION
Systems and methods are disclosed. The method includes obtaining a reservoir model (216) and a production scenario. The method also includes determining a first set of parameters for a first time from the reservoir model (216) and the production scenario, predicting, using the first set of parameters, a second set of parameters at a second, later, time, including primary variables used to determine values for a mass, a flux and a well term. Predicting includes, iteratively until a stopping criterion is satisfied, for each computational cells (218) in the reservoir model (216), using the first set of parameters to determine a primary variable update and a residual, determining an updated flux and well term, predicting the second set of parameters from the updated flux and well term, assigning the second set of parameters to the first set of parameters, and determining a predicted location of unproduced hydrocarbons from the second set of parameters.
42 - Scientific, technological and industrial services, research and design
Goods & Services
Software as a service (SAAS) services featuring software using artificial intelligence (AI) for reservoir modeling and subsurface analysis; Providing on-line non-downloadable software using artificial intelligence (AI) for reservoir modeling and subsurface analysis
87.
Real-time detection of gas kicks during drilling and gas cap gas intrusion during oil production
A method of detecting an increase in gas content in a pipe. The method includes flowing fluid through the pipe. The method includes generating, by a network analyzer, microwaves data representing a complex scattering coefficient over a first spectrum of microwave frequencies that are emitted through a waveguide and a fluid within the pipe and determining a statistical profile of a complex scattering magnitude over a second spectrum of microwave frequencies. The method includes determining that an amount of gas within the pipe satisfies a threshold amount and causing a flow of fluids within the pipe to slow or stop until the amount of gas falls below a predetermined threshold value.
E21B 47/113 - Locating fluid leaks, intrusions or movements using electrical indicationsLocating fluid leaks, intrusions or movements using light radiation
G01N 22/00 - Investigating or analysing materials by the use of microwaves or radio waves, i.e. electromagnetic waves with a wavelength of one millimetre or more
88.
Cuttings trap for “at bit” measurement of drilled cuttings
A cuttings collection system includes a drill bit at the end of a toolstring, a stabilizer connected to the drill bit, a cuttings catcher arranged around the stabilizer with apertures having a size less than an average size of cuttings generated by the drill bit and retractability, and sensors installed in a body of the stabilizer. A cuttings catcher includes a housing with recesses and a retractable mesh installed in each of the recesses. A method of operating an at-bit cuttings catcher system includes providing a toolstring with a drill bit, a stabilizer, a cuttings catcher, and a measurement-while-drilling tool, where the cuttings catcher includes a housing with recesses and a mesh installed in the recesses, drilling a formation using the drill bit, producing cuttings of the formation, extending the mesh from the housing of the cuttings catcher, catching cuttings in the cuttings catcher, and analyzing the cuttings using sensors.
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
42 - Scientific, technological and industrial services, research and design
Goods & Services
Software as a service (SAAS) for reservoir modeling and subsurface analysis; software as a service (SAAS) services featuring software using artificial intelligence (AI) for reservoir modeling and subsurface analysis; providing online non-downloadable software for reservoir modeling and subsurface analysis; providing online non-downloadable software using artificial intelligence (AI) for reservoir modeling and subsurface analysis.
90.
DETECTION AND RECORDING OF BLOW OUT PREVENTER RAM OPERATIONS DURING RIG-LESS WELLBORE INTERVENTIONS
A rig-less wellbore system includes a blowout preventer (BOP) central body fluidly coupled to a wellbore and a plurality of hydraulic cylinders extending radially from the central body. A plurality of pistons operable to move radially within a respective hydraulic cylinder between an open position wherein flow through the central passageway is permitted and a closed position wherein the pistons extend into the central passageway to prohibit fluid flow through the central passageway. At least one sensor is operable to monitor at least one parameter indicative of activity within a hydraulic circuit operably associated with an individual one of the pistons. A data acquisition system (DAS) is communicatively coupled to the at least one sensor to collect and record data provided by the at least one sensor.
Methods of subterranean carbon dioxide storage may include: introducing, through an injection wellbore to a subterranean formation includes a basaltic formation, a carbonated aqueous fluid; reacting the carbon dioxide or an ion thereof with the basaltic formation to form mineralized carbon and a produced aqueous fluid; flowing a mixture of the carbonated aqueous fluid and/or the produced aqueous fluid through one or more formation fractures; depositing the mineralized carbon dioxide within the subterranean formation; and flowing the produced aqueous fluid from the subterranean formation through a first production wellbore, wherein a portion of the first production wellbore is substantially parallel to a portion of the injection wellbore, and wherein the one or more formation fractures are substantially perpendicular to a portion of the injection wellbore and a portion of the first production wellbore.
A fire extinguishing system includes a storage tank defining a vertical wall and a floating roof floating on a flammable liquid stored within the storage tank. The floating roof is vertically movable along the vertical wall in response to a level of the flammable liquid within the storage tank and a rim seal is defined circumferentially between the floating roof and the vertical wall. A foam supply conduit extends to the storage tank from a remote location and a foam diffuser is fluidly coupled to the foam supply conduit. The foam diffuser is affixed to an underside of the floating roof and submerged in the flammable liquid. The foam diffuser includes at least one outlet for discharging a foam into the flammable liquid adjacent the underside of the floating roof and an upper surface of the flammable liquid.
A system for pumping a fluid into a sub-surface formation to pressurize the sub-surface formation using a pump having a shaft. The system includes a mechanical seal removably installed in the pump and a mechanical seal integrity testing rig configured to be pressed against the mechanical seal and to test an integrity of the mechanical seal. The mechanical seal removably installed in the pump comprises a mechanical seal sleeve delineating a conduit configured to receive the shaft of the pump and a bottom end and a mechanical seal flange. The system further includes a mechanical seal integrity testing rig configured to be pressed against the mechanical seal and to test an integrity of the mechanical seal. The mechanical seal integrity testing rig comprises a testing rig sleeve having a top end of testing rig sleeve and a bottom end of testing rig sleeve and a mechanical seal sleeve blind.
G01M 3/28 - Investigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables, or tubesInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipe joints or sealsInvestigating fluid tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for valves
F04B 47/04 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level the driving means incorporating fluid means
F04B 51/00 - Testing machines, pumps, or pumping installations
94.
SYSTEMS AND METHODS FOR PREPARING AND QUANTIFYING SOLUTIONS
Systems and methods for the preparation and quantification of chemical solutions. The system includes a working solution preparation section, a standard solution preparation section, and a titration section.
G01N 35/10 - Devices for transferring samples to, in, or from, the analysis apparatus, e.g. suction devices, injection devices
G01N 31/16 - Investigating or analysing non-biological materials by the use of the chemical methods specified in the subgroupsApparatus specially adapted for such methods using titration
A circular economy polygeneration system includes an electrolyzer operable to provide hydrogen and oxygen based on water. The system includes a hydrogen firing furnace operable to burn hydrogen and produce a first flue gas including water and nitrogen. The system also includes an oxy-firing furnace operable to burn hydrocarbon fuel with oxygen provided by the electrolyzer to produce a second flue gas comprising water and carbon dioxide. Moreover, the system includes a first condenser configured to produce nitrogen and a first stream of water based on the first flue gas. The system further includes a second condenser configured to produce carbon dioxide and a second stream of water based on the second flue gas. The first and second stream of water are used by the electrolyzer to provide the hydrogen and oxygen. Additionally, the system includes a carbon capture system operable to capture carbon dioxide produced by the second condenser.
F23C 9/00 - Combustion apparatus characterised by arrangements for returning combustion products or flue gases to the combustion chamber
B01D 53/00 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols
A computer implemented method that enables dynamic digital analysis of chemical inhibitors utilizing machine learning is described. The method includes determining a concentration output using a machine learning model trained using data associated with thermodynamic chemical inhibitors; determining temperatures associated with a chemical inhibitor regeneration cycle using a machine learning model trained using temporal data; determining a liquid inventory using a machine learning model trained using data associated with flow rates; generating a model of a chemical inhibitor regeneration cycle based on the concentration output, the temperatures, and the liquid inventory; and executing the model by inputting real-time operating conditions associated with the chemical inhibitor regeneration cycle, wherein the model outputs chemical inhibitor concentrations associated with a production system.
G05B 13/02 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric
Systems and methods for measuring rock permeability include positioning a core sample in a core sample assembly that is enclosed in a pressurized container with a flow inlet, a flow outlet, and a pressurized fluid inlet fluidly coupled to a pressurized fluid reservoir that includes a pressurized fluid pump; performing a low pore pressure test operation on the core sample; sequentially performing at least three high pore pressure test operations on the core sample measuring an inlet pressure at the flow inlet, measuring an outlet pressure at the flow outlet, and measuring a confining pressure within the pressurized container; and determining a permeability of the core sample based at least in part on at least one of the measured inlet pressures, at least one of the measured outlet pressures, and at least one of the measured confining pressures.
A heater cable is disposed through a wellhead assembly into a production tubing string and is lowered such that it is at least partially immersed within a volume of a well kill fluid. Prior to the immersion, a density of the well kill fluid relative to the produced fluids at the downhole end is such that the volume of well kill fluid prevents the flow of the produced fluids from the subterranean zone into the production tubing string. An electric current is flowed though the heater cable, and the heater cable converts the electric current to heat energy. The heat energy is transferred by conduction to the kill fluid thereby reducing the density of the well kill fluid relative to the produced fluids such that the well kill fluid rises in an uphole direction through the production tubing string.
An autonomous machine includes a body; a mobile base coupled to the body and configured to move the body between a plurality of locations; and at least one extendable appendage coupled to, and configured to extend from, the body. The at least one extendable appendage includes at least one laser sensor plate. The at least one laser sensor plate includes at least one laser emitter configured to move on the at least one laser sensor plate and emit a laser signal along a tubular member; and at least one laser receiver coupled to the at least one laser sensor plate and configured to receive a reflected laser signal along the tubular member. The emitted laser signal and the reflected laser signal is indicative of a quality of the tubular member.
A composition and methods are provided for stimulating a well with nanobubbles. An exemplary method includes obtaining a stimulation fluid and generating a nanobubbles solution, wherein the nanobubbles solution includes nano-sized bubbles in the stimulation fluid. The nanobubbles solution is injected into the oil well.
