This disclosure describes systems and methods for unobtrusively and adaptively displaying a watermark on a display screen based on context sensing and behavior analytics. The techniques can include receiving from a sensor of a user device, information about a focus of attention of a user viewing a display screen of the computing device; determining a placement of a perceptible watermark for displaying onto the display screen based, at least in part, on the focus of attention of the user; causing media content to be displayed on the display screen; and causing the watermark to be displayed on the display screen in a position on the display screen based on the focus of attention of the user.
A hydraulic fracturing fluid and methods for using the hydraulic fracturing fluid fracturing a formation are provided. An exemplary hydraulic fracturing fluid includes a polymer additive, a breaker, a non-ionic surfactant. The hydraulic fracturing fluid also includes an amphoteric surfactant, or a cationic surfactant, or both, and a base fluid.
An encapsulated apparatus (200) includes an external housing (202) and an internal housing (204). The external housing (202) includes a plurality of components (206) including a motor head (208), a motor (118), and a pump intake (130). The motor head (208) has a fluid outlet (210) configured to direct reservoir fluid out of the motor head (208). The motor head (208) includes a power inlet (214) configured to connect a power cable to an electric transmission system (216). The motor (118) is connected to the motor head (208) in contact with the reservoir fluid. The motor is powered by the electric transmission system (216). The pump intake (130) is connected to the motor (118) having a fluid inlet (212) configured to direct the reservoir fluid from the fluid outlet (210) into the fluid inlet (212). The internal housing (204) is disposed in the external housing (202) configured to be fluidly isolated from the reservoir fluid. The internal housing (204) includes the electric transmission system (216).
A wellbore tubular (151a) including a pre-installed data transmission cable is disclosed. The tubular includes a hollow cylinder, a stationary ring (152b) disposed at the lower end of the cylindrical wall and having a lower end hollow pin (153b) protruding downward from the stationary ring (152b), a rotating ring (152a) disposed at the upper end of the cylindrical wall and having an upper end hollow pin (153a) protruding upward from the rotating ring (152a), a rigid conduit disposed inside the hollow cylinder and extending from the lower end hollow pin (153b) to beneath the rotating ring (152a), an elastic conduit disposed inside the hollow cylinder to extend the rigid conduit from beneath the rotating ring (152a) to the upper end hollow pin (153a), and a data transmission cable routed from the lower end hollow pin (153b) to the upper end hollow pin (153a) through the rigid conduit and the elastic conduit.
In one aspect, a magnetic drone (100) is disclosed. The magnetic drone includes a drone (102), a cage (104) surrounding the drone (102), and one or more magnets (106) disposed on the cage (104) surrounding the drone (102). The drone (102) includes a camera, a battery, one or more electric motors, and one or more propellers (108). In other aspects, a method to operate a magnetic drone (100) and a non-transitory computer readable medium storing instructions for performing operation that flies a magnetic drone (100) are also disclosed.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
Inventor
Hernandez, Carlos Daniel Rodriguez
Abdelaziz, Ahmed Amr Mohamed Hafez
Finkbeiner, Thomas
Santamarina, Juan Carlos
Arfaj, Mohammad
Alouhali, Raed A.
Moellendick, Timothy Eric
Abstract
Lost circulation materials may be particles having a core-shell structure. Said particles may include: a core comprising an expandable material; and a shell around the core, the shell comprising an outer permeable membrane, an inner permeable membrane, and a hardenable material between the outer and inner permeable membranes; and wherein the core-shell structure is folded. The particles may be initially folded where, upon exposure to a stimulus, the core expands in volume (which unfolds the particles) and the shell increases in strength. The expanded particles can then clog large openings / apertures in the formation.
C09K 8/504 - Compositions based on water or polar solvents
C09K 8/506 - Compositions based on water or polar solvents containing organic compounds
C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
7.
SELF-AGGREGATING PARTICLES FOR LOST CIRCULATION MATERIALS AND RELATED METHOD
ALI I. AL-NAIMI PETROLEUM ENGINEERING RESEARCH CENTER KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
Inventor
Abdelaziz, Ahmed Amr Mohamed Hafez
Liu, Qi
Finkbeiner, Thomas
Santamarina, Juan Carlos
Arfaj, Mohammad
Alouhali, Raed A.
Moellendick, Timothy Eric
Abstract
Lost circulation materials may include a plurality of self-aggregating particles having a degradable coating, wherein the self-aggregating particles are capable of bonding via mechanical interactions, electrical interactions, magnetic interactions, chemical interactions, or any combination thereof into a plurality of aggregated particles. The aggregated particles have a larger effective size and can seal large openings / apertures in the subsurface that cause lost circulation during a wellbore drilling operation.
C09K 8/03 - Specific additives for general use in well-drilling compositions
C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
8.
GENERATE HYDROGEN AS FUEL AT NATURAL GAS PROCESSING PLANT TO REDUCE CARBON DIOXIDE EMISSIONS
Operating a natural gas (NG) processing plant, including receiving feed natural gas and processing the feed natural gas to give product natural gas. The processing includes removing acid gas, water, and non-methane hydrocarbons from the feed natural gas. In the NG processing plant, fuel is provided to a furnace and combusted in the furnace to heat a boiler and an HRSG to generate HP steam that drives a turbine to generate electricity and convert the HP steam to LP steam. Excess LP steam in the NG processing plant is subjected to electrolysis, thereby generating hydrogen gas, and the hydrogen gas combined with the fuel for combustion in the furnace.
F01K 17/04 - Use of steam or condensate extracted or exhausted from steam engine plant for specific purposes other than heating
F01K 17/06 - Returning energy of steam, in exchanged form, to process, e.g. use of exhaust steam for drying solid fuel of plant
C10L 3/10 - Working-up natural gas or synthetic natural gas
F22B 1/18 - Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
F01K 19/00 - Regenerating or otherwise treating steam exhaust from steam engine plant
9.
PRODUCING HYDRO-EFFLUX HAMMER USING CATALYST-FREE PDC CUTTERS
Cutters for a downhole drill bit can be formed by providing a catalyst-free synthesized polycrystalline diamond (PCD) having a cross-sectional dimension of at least 8 millimeters; providing a substrate comprising tungsten carbide; and attaching the synthesized PCD to the substrate comprising tungsten carbide to form a PDC cutter.
E21B 1/38 - Hammer piston type, i.e. in which the tool bit or anvil is hit by an impulse member
E21B 10/40 - Percussion drill bits with leading portion
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
10.
METHODS FOR QUANTIFYING AND TRACKING AMINE-BASED SHALE INHIBITORS IN DRILLING FLUIDS
Described is a method for quantifying and tracking an amine-based shale inhibitor in a drilling fluid through UV-visible spectroscopy. A correlation is determined between varying concentrations of an amine-based shale inhibitor (100) in a water-based drilling fluid sample and an ultraviolet (UV)-visible absorption intensity. A calibration plot is generated based on the correlations. Samples of a circulating drilling fluid having an unknown concentration of amine-based shale inhibitor (100) are obtained. Using the calibration plot, the concentration of amine-based shale inhibitor (100) in the samples of the circulating drilling fluid is estimated.
G01N 21/33 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using ultraviolet light
A method for predicting total organic carbon (TOC) and sensitive elements related to unsampled intervals of a well, is provided. The method includes obtaining first log data related to sampled intervals of a well, the first log data comprising a plurality of parameters corresponding to one or more of TOC data and sensitive elements data associated with the sampled intervals, generating a model representing a nonlinear relationship between the first log data and the TOC data and sensitive elements data using a machine learning engine, obtaining second log data related to unsampled intervals of the well, and determining predicted TOC and predicted sensitive elements associated with the unsampled intervals of the well using the model and the second log data.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
12.
MESOPOROUS ZEOLITES AND METHODS OF MAKING THE SAME
A method of making a mesoporous zeolite may include combining an initial zeolite with cetyltrimethylammonium bromide to form an initial zeolite mixture. The method may also include adding ammonium hexafluorosilicate and ammonium hydroxide to the initial zeolite mixture to form a treated zeolite mixture. The method may also include heating the treated zeolite mixture to form the mesoporous zeolite.
C01B 39/02 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof; Direct preparation thereof; Preparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactants; After-treatment thereof
An assembly and a method for cooling a downhole logging tool. The assembly includes a coiled tubing assembly having a downhole logging tool and a coiled tubing pipe. The coiled tubing pipe is coupled to the downhole logging tool. The coiled tubing pipe includes a cooling fluid tube. The cooling fluid tube conducts a cooling fluid to the downhole logging tool.
A method of analyzing a downhole fluid includes performing measurements of a dielectric property of the downhole fluid, the downhole fluid including a mixture of a filtrate fluid circulated through a borehole and a connate fluid. The measurements include a first measurement of the downhole fluid, and one or more additional measurements, each additional measurement performed after an amount of the filtrate fluid is injected into the downhole fluid to change the volume ratio, each additional measurement performed when the downhole fluid has a different volume ratio. The method also includes acquiring a plurality of reference profiles of respective reference mixtures, the respective reference mixtures including a first fluid and a reference fluid, comparing the measurements to each reference profile, and estimating a value of the dielectric property of the connate fluid based on the comparing.
Operating a natural gas processing plant, including receiving feed natural gas and processing the feed natural gas to give product natural gas. The processing includes removing acid gas, water, and non-methane hydrocarbons from the feed natural gas. The method includes providing fuel to a furnace and combusting the fuel in the furnace to heat a boiler to generate steam. The method generating steam with an HRSG. The method includes subjecting blowdown water from the boiler and the HRSG to electrolysis, thereby generating hydrogen gas. The method includes combining the hydrogen gas with the fuel and combusting the hydrogen gas in the furnace.
Systems and methods for modeling gas desorption in a subterranean reservoir include measuring a gas sorption parameter using a crushed core sample from the subterranean reservoir; computing a gas storage capacity of the subterranean reservoir at an initial reservoir pressure based on the gas sorption parameter; generating a three-dimensional (3D) distribution of total organic carbon (TOC) in the subterranean reservoir; estimating a 3D distribution of original adsorbed gas in place of the subterranean reservoir by correlating the gas storage capacity with the 3D distribution of TOC; and predicting the amount of gas desorbed from the subterranean reservoir as the reservoir is depleted.
Example computer-implemented methods, media, and systems for identifying and quantifying diagenetically produced cemented subsurface geobodies are disclosed. One example computer-implemented method includes obtaining one or more borehole logs of one or more wells in a subsurface reservoir. A functional relationship between acoustic impedance of the subsurface reservoir and volume of diagenetically produced cemented geobody in the subsurface reservoir is determined based on the one or more borehole logs. Multiple acoustic impedance cubes of the subsurface reservoir is obtained. Multiple volumes of diagenetically produced cemented geobodies in the subsurface reservoir is determined based on the functional relationship and the multiple acoustic impedance cubes of the subsurface reservoir, where the multiple volumes correspond to the multiple acoustic impedance cubes of the subsurface reservoir. Locations of the diagenetically produced cemented geobodies in the subsurface reservoir are mapped using the determined multiple volumes of the diagenetically produced cemented geobodies.
A well system includes a local controller (124) communicably coupled to a hydraulic diverter (125) configured to control a well shut-in assembly (121) at a well site operable to shut in a wellbore (108) based on a command from the local controller (124) or to shut in or open the wellbore (108) based on a command from a control panel (120, 122) at or in a vicinity of the well site. The well system includes a remote controller located at a location remote from the local controller (124) and the well site and configured to communicate a wireless signal to the local controller (124) to initiate the command from the local controller (124). The well system includes the hydraulic diverter (125) fluidly coupled to the well shut-in assembly (121). The hydraulic diverter (125) is configured to, based on the command from the local controller (124), control the well shut-in assembly (121) to shut in the wellbore (108) and render the command from the control panel (120, 122) irrelevant.
Compositions of a calcium lignosulfonate salt having a chemical structure (I), wherein a total number of guaiacyl groups is 2 to 10. The compositions may further include an alcohol, an aldehyde, and water. Cement slurries may include a lignosulfonate-based cement dispersant including a calcium lignosulfonate salt having a chemical structure (I), an alcohol, an aldehyde, and water, wherein a total number of guaiacyl groups in the chemical structure (I) is 2 to 10. Also, methods of introducing a cement slurry into a wellbore penetrating a subterranean formation, wherein the cement slurry comprises a lignosulfonate-based cement dispersant, a cement, and water, and allowing the cement slurry to set to a concrete in a downhole zone of interest.
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
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
20.
COMPOSITIONS AND METHODS FOR BRANCHED CALCIUM LIGNOSULFONATE CEMENT DISPERSANTS
Compositions of a calcium lignosulfonate salt having a chemical structure (I), wherein a total number of syringyl groups is 2 to 10. The compositions may further include an alcohol, an aldehyde, and water. Cement slurries including the lignosulfonate-based cement dispersant including a calcium lignosulfonate salt having a chemical structure (I), an alcohol, an aldehyde, and water, wherein a total number of syringyl groups in the chemical structure (I) is 2 to 10. Methods including introducing a cement slurry into a wellbore penetrating a subterranean formation, wherein the cement slurry comprises a lignosulfonate-based cement dispersant, a cement, and water, and allowing the cement slurry to set to a concrete in a downhole zone of interest.
C04B 24/18 - Lignin sulfonic acid or derivatives thereof, e.g. sulfite lye
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
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
21.
METHOD AND SYSTEM FOR PERFORMING SEISMIC INVERSION USING A CONVOLUTION-BASED OBJECTIVE FUNCTION
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
He, Weiguang
Sui, Yuhan
Du, Yue
Abstract
A method may include obtaining acquired seismic data based on a seismic survey regarding a geological region of interest. The method may further include generating synthetic seismic data for the geological region of interest using a forward modeling function and a velocity model. The method may further include determining an objective function using the acquired seismic data, the synthetic seismic data, and a convolution function. The method may further include determining whether the velocity model satisfies a predetermined criterion based on the objective function. The method may further include updating, in response to determining that the velocity model fails to satisfy the predetermined criterion, the velocity model using a search method and various gradients to produce an updated velocity model. The method may further include generating a seismic image using the updated velocity model. A system and a non-transitory computer readable medium are also included.
According to one embodiment of the present disclosure, a method of processing a hydrocarbon feed includes fractionating the hydrocarbon feed into a light stream and a heavy stream; hydrotreating the heavy stream to form a hydrotreated heavy stream; feeding the light stream and the hydrotreated heavy stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream which includes light olefins. The light stream may be exposed to more severe FCC cracking conditions than the heavy stream, within the same FCC reaction zone. The single FCC reaction zone may be operated in a down-flow configuration and the FCC may be operated under high severity conditions. The light stream may include hydrocarbons boiling at less than 371 ⁰C and the heavy stream may include hydrocarbons boiling at greater than 371 ⁰C.
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
A method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream and a heavy stream, where the light stream includes hydrocarbons boiling at less than 370 ⁰C, and the heavy stream includes hydrocarbons boiling at greater than greater than 370 ⁰C, hydrotreating the heavy stream to form a hydrotreated heavy stream, feeding the light stream to a first Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a light product stream which includes light olefins, and feeding the hydrotreated heavy stream to a second Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a heavy product stream which includes light olefins, where the first FCC reaction zone operates under more severe operating conditions than the second FCC reaction zone.
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 51/06 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only plural parallel stages only
C10G 69/02 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
A method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream, a middle stream and a heavy stream; hydrotreating the heavy stream to form a hydrotreated heavy stream; feeding the light stream to a first Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a light product stream comprising light olefins; feeding the middle stream to a second FCC reaction zone, thereby producing a middle product stream comprising olefins; and feeding the hydrotreated heavy stream to a third Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a heavy product stream comprising light olefins. The light stream may comprise hydrocarbons boiling at less than 200 ⁰C. The middle stream may comprise hydrocarbons boiling at from 200 ⁰C to 370 ⁰C. The heavy stream may comprise hydrocarbons boiling at greater than greater than 370 ⁰C. Each of the first and second FCC reaction zones may operate under more severe operating conditions than the third FCC reaction zone.
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
A method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream, a middle stream and a heavy stream; hydrotreating the heavy stream to form a hydrotreated heavy stream; feeding the light stream to a first Fluid Catalytic Cracking (FCC) reaction zone; feeding the middle stream to a second FCC reaction zone; and feeding the hydrotreated heavy stream to a third FCC reaction zone, thereby producing a heavy product stream comprising light olefins; and feeding one or more of the product streams to one or more fractionators, thereby producing one or more finished product streams and one or more recycle streams comprising one or more of light cycle oil (LCO), heavy cycle oil (HCO), and slurry oil; and hydrotreating one or more of the recycle streams to form the hydrotreated heavy stream.
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
26.
UPDATING SUBSURFACE STRUCTURAL MAPS WITH WELL-MEASURED ORIENTATION DATA WHILE PRESERVING LOCAL GEOLOGICAL STRUCTURES
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Ma, Yue
Ji, Xu
Albinhassan, Nasher Muqbel
Abstract
Examples of methods and systems are disclosed. The methods may include, obtaining a seismic dataset(400) regarding a subsurface region of interest and obtaining a well log for each of a plurality of wellbores(410) penetrating the subsurface region of interest. The methods may also include determining a geological surface from the seismic dataset(420), wherein the geological surface includes seismic-estimated orientation data estimated at a plurality of points on the geological surface. The methods may further include determining an intersection point for each of the plurality of wellbores with the geological surface, wherein the intersection point includes well-measured orientation data(430). The methods may still further include generating an updated geological surface by updating the seismic-estimated orientation data at the plurality of points on the geological surface based, at least in part, on the well-measured orientation data(440).
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Sui, Yuhan
Ma, Yue
Liu, Hongwei
Zhang, Dongliang
Abstract
A system and methods are disclosed. The method includes obtaining a seismic dataset including a plurality of recorded multiple events(500), generating a predicted multiple model using a multiple prediction method and the seismic dataset(504), and estimating a set of initial matching filters using a matching method, to match the plurality of estimated and recorded multiple events(506). The method further includes generating a tensor field based on the predicted multiple model(508), determining a set of structure-oriented matching filters based on the set of initial matching filters and the tensor field(510), generating a filtered multiple model based on the predicted multiple model and the set of structure-oriented matching filters(512), and generating a multiple-attenuated seismic dataset based on the filtered multiple model and the seismic dataset(514), forming a seismic image based, at least in part, on the multiple-attenuated seismic dataset(516), and determining a location of a hydrocarbon reservoir based on the seismic image(518).
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
A method and system for labeling and identifying a sample (202), including a rock core sample (202), after determining a physical primary label (204) has been compromised is provided. The method includes labeling the sample (202) by placing a physical primary label (204) on the sample (202) or sample container (206), creating a first rollout image of the sample (202) for a secondary label, and storing the first rollout image in a secondary label digital database with a sample identifier. The method continues for identifying the sample (202) after determining the physical primary label (204) has been compromised by creating a second rollout image of the sample (202) and searching the secondary label digital database using the second rollout image to create a plurality of matching scores using a machine learning or deep learning image matching technique. The matching scores are then evaluated to determine an identity of a sample (202) and the sample (202) is re-labelled using a replacement primary label (204).
A method and a system for dehydrating a gas stream while recovering energy are provided. An exemplary method includes sending a lean glycol stream to a glycol contactor, contacting a wet gas with the lean glycol stream in the glycol contactor, forming a rich glycol stream. The rich glycol stream from the glycol contactor is passed through an energy recovery unit, forming a low-pressure stream. The low-pressure stream is fed to a glycol regeneration column. Power from the energy recovery unit is used to generate a vacuum in the glycol regeneration column.
B01D 53/14 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream, a middle stream, a heavy stream, and a residue stream; hydrotreating the residue stream to form a hydrotreated residue stream; and feeding the light stream, middle stream, heavy stream, and the hydrotreated residue stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream comprising light olefins. The light stream and the hydrotreated residue streams may be exposed to more severe FCC cracking conditions than the middle stream and the middle stream may be exposed to more severe FCC cracking conditions than the heavy stream. The FCC reaction zone may be operated in a down- flow configuration and operated under high severity conditions.
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
According to one embodiment of the present disclosure, a method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream, a middle stream, and a residue stream, hydrotreating the residue stream to form a hydrotreated residue stream; and feeding the light stream, middle stream, and the hydrotreated residue stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream comprising light olefins. The light stream and the hydrotreated residue streams may be exposed to more severe FCC cracking conditions than the middle stream, within the same FCC reaction zone. The single FCC reaction zone may be operated in a down-flow configuration and the single FCC reaction zone may be operated under high severity conditions.
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 51/02 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only plural serial stages only
Embodiments of the present disclosure are directed to a method of processing a hydrocarbon feed includes fractionating the hydrocarbon feed into a light stream and a heavy stream, hydrotreating the heavy stream to form a hydrotreated heavy stream, combining the light stream and the hydrotreated heavy stream to form a upgraded feed stream, and feeding the upgraded feed stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream comprising light olefins. The light stream may comprise hydrocarbons boiling at less than 540 ⁰C and the heavy stream may comprise hydrocarbons boiling at greater than 540 ⁰C. The FCC reaction zone may be operated in a down-flow configuration and the FCC may be operated under high severity conditions.
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
A method of processing a hydrocarbon feed may comprise fractionating the hydrocarbon feed into a light stream, a middle stream, and a heavy stream; hydrotreating the heavy stream to form a hydrotreated heavy stream; and feeding the light stream, middle stream, and the hydrotreated heavy stream to a single Fluid Catalytic Cracking (FCC) reaction zone, thereby producing a product stream comprising light olefins. The light stream may be exposed to more severe FCC cracking conditions than the middle stream and the middle stream may be exposed to more severe FCC cracking conditions than the hydrotreated heavy stream, within the same FCC reaction zone. The single FCC reaction zone may be operated in a down-flow configuration and under high severity conditions.
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
C10G 45/44 - Hydrogenation of the aromatic hydrocarbons
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
34.
CORROSION-FREE WELDED CONNECTION FOR REINFORCED THERMOPLASTIC PIPES (RTP)
A connection system (100) for reinforced thermoplastic polymer (RTP) pipe includes a first pipe (110) having a first end (111) and a reinforced thermoset resin (RTR) coupler (120) positioned adjacent the first end (111) of the first pipe (110). The RTR coupler (120) has an annular body (201) with a first socket extension (204) extending into the first end (111) of the first pipe (110) and a first thermoplastic tie layer (210) provided between the first socket extension (204) and the first end (111) of the first pipe (110). A first set of wedges (140) is positioned circumferentially around an outer surface of the first end (111) of the first pipe (110), and a first flange (150) is fitted around the first set of wedges (140), wherein the first set of wedges (140) is wedged between the first end (111) and the first flange (150).
F16L 47/03 - Welded joints with an electrical resistance incorporated in the joint
B29C 65/36 - Joining of preformed parts; Apparatus therefor by heating, with or without pressure using heated elements which remain in the joint, e.g. "verlorenes Schweisselement" heated by induction
F16L 47/06 - Connecting arrangements or other fittings specially adapted to be made of plastics or to be used with pipes made of plastics with sleeve or socket formed by or in the pipe end
A system (100) includes: one or more containers (110), each containing a liquid; an oven (150); and a sample chamber (140) disposed in the oven, wherein a sample having an initial weight is disposed in the sample chamber, the oven is configured to heat the sample chamber to an elevated temperature, and the sample chamber is configured to hold an elevated pressure, and one or more of the liquid from the one or more containers form a treatment solution that is configured to dissolve a portion of the sample under the elevated temperature and the elevated pressure.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities
G01N 5/04 - Analysing materials by weighing, e.g. weighing small particles separated from a gas or liquid by removing a component, e.g. by evaporation, and weighing the remainder
G01N 1/00 - Sampling; Preparing specimens for investigation
36.
SCALE/CORROSION INHIBITOR DISPENSER FOR WELLBORE PROTECTION
A chemical dispenser system (300) includes a Y-tool (200) secured to a toolstring (117) via a Y-block (202), the Y-tool comprising a bypass line (206) and a pump line (204), where the bypass line (206) and the pump line (204) are fluidly connected to the toolstring (117) at an upper end of the Y-block (202) and where the pump line (204) and the bypass line (206) are arranged parallel to each other. The chemical dispenser system (300) further includes an electrical submersible pump (124) provided in the pump line (204), inhibitor chemicals (304) held within one or more pressure retaining chambers (302) in the bypass line (206), and a blanking plug (214) landed in the bypass line (206).
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
37.
METHOD AND SYSTEM FOR AUTOMATED INSTALLATION OF WELDED REINFORCED THERMOSETTING RESIN PIPE JOINTS
A system and method for automatically jointing of reinforced thermosetting resin (RTR) pipes, having an inductor (500) and a pig (600) for automated in-field installation of RTR pipes (302, 304). The inductor (500) is fitted on an outside of the RTR joint (300). Additionally, the pig (600) is inserted inside the pipeline and remotely controlled to assist operators during the alignment of the pipes (302, 304) and subsequent joint making/welding. Through the successive inflation and deflation of pneumatic wheels (604) placed along the pig (600), the pig (600) may autonomously move inside the RTR pipeline (from one RTR joint (300) to the other) during the installation, while also being used to apply internal pressure at specific locations of the pipe (302, 304), as needed, during installation.
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Alghanmi, Abdulmalik, Abdullah
Al-Qasim, Abdulaziz, S.
Abstract
A drone system includes a headquarter station and one or more drone port stations (200). Each drone port station (200) includes a platform (202) configured to receive a drone, a radar system (208) configured to detect and identify the drone, and one or more locker clips (204) disposed on the platform (202), wherein the one or more locker clips (204) are configured to lock onto one or more legs extending from the drone. Each drone port station (200) also includes an internal computer (210) configured to control operations of the drone port station (200), an internal camera (216) operatively connected to the internal computer (210), where the internal camera (216) is configured to detect a charging port or a fuel tank of the drone, a glass panel placed on the platform (202), where the glass panel is configured to protect the internal camera (216), and an antenna (106) extending from the platform (202) and configured to provide a communications pathway from the drone port station (200) to the headquarter station.
B64U 70/95 - Means for guiding the landing UAV towards the platform, e.g. lighting means
B64U 70/99 - Means for retaining the UAV on the platform, e.g. dogs or magnets
B64U 80/25 - Transport or storage specially adapted for UAVs with arrangements for servicing the UAV for refuelling
B64U 80/30 - Transport or storage specially adapted for UAVs with arrangements for data transmission
G01S 7/41 - RADIO DIRECTION-FINDING; RADIO NAVIGATION; DETERMINING DISTANCE OR VELOCITY BY USE OF RADIO WAVES; LOCATING OR PRESENCE-DETECTING BY USE OF THE REFLECTION OR RERADIATION OF RADIO WAVES; ANALOGOUS ARRANGEMENTS USING OTHER WAVES - Details of systems according to groups , , of systems according to group using analysis of echo signal for target characterisation; Target signature; Target cross-section
G01S 13/04 - Systems determining presence of a target
G01S 13/86 - Combinations of radar systems with non-radar systems, e.g. sonar, direction finder
Methods comprising: introducing an aqueous carrier fluid comprising an ammonium phosphate salt into a subterranean formation comprising a carbonate mineral; and interacting the carbonate mineral with the ammonium phosphate salt to convert at least a portion of the carbonate mineral into a hydroxyapatite mineral; wherein the subterranean formation has an increased hardness after forming the hydroxyapatite mineral
Provided is a crosslinking agent (100) that has a core particle (102) and a shell (104) on the surface of the core particle (102). The shell (104) has at least one polymacrolactone. Also provided is a polymeric composite (208) including a polyolefin matrix having at least one polyolefin (202) and the crosslinking agent (204). The polyolefin is functionalized to include functional groups. Further, a method of preparing the polymeric composite composition and an article are provided.
C08L 51/06 - Compositions of graft polymers in which the grafted component is obtained by reactions only involving carbon-to-carbon unsaturated bonds; Compositions of derivatives of such polymers grafted on to homopolymers or copolymers of aliphatic hydrocarbons containing only one carbon-to-carbon double bond
C08J 3/24 - Crosslinking, e.g. vulcanising, of macromolecules
41.
METHODS FOR INCREASING THE HARDNESS OF SUBTERRANEAN FORMATIONS
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Samarkin, Yevgeniy
Aljawad, Murtada Saleh
Amao, Abduljamiu Olalekan
Al-Tammar, Murtadha J.
Alruwaili, Khalid Mohammed
Abstract
Methods comprising: introducing an aqueous carrier fluid comprising an ammonium phosphate salt into a subterranean formation comprising a carbonate mineral; and interacting the carbonate mineral with the ammonium phosphate salt to convert at least a portion of the carbonate mineral into a hydroxyapatite mineral; wherein the subterranean formation has an increased hardness after forming the hydroxyapatite mineral.
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
He, Yi
Liu, Yujin
Liu, Hongwei
Qin, Fuhao
Du, Yue
Abstract
Methods of parallel cross spread sorting for seismic data are disclosed. The methods include obtaining a seismic data set (300) comprising a plurality of shot gathers; dividing headers (200) from the plurality of shot gathers among a plurality of computer nodes (222); sorting the headers (200) separately on each of the plurality of computer nodes (222); saving the sorted headers (226) from the plurality of computer nodes (222) to a temporary file (206); sorting the sorted headers (226) saved to the temporary file (206) into a cross spread gather ordering; and sorting seismic traces according to the cross spread gather ordering to create cross spread gathers (410). The methods further include applying a seismic imaging algorithm to the cross spread gathers (410) to create a seismic image (425). A non-transitory computer-readable memory and a system are also disclosed.
Systems and/or computer-implemented methods that can estimate an amount of electrical power that can be generated from a geothermal subsurface reservoir. One or more embodiments described herein can include a system, which can comprise a memory to store computer executable instructions. The system can also comprise one or more processors, operatively coupled to the memory, which can execute the computer executable instructions to implement a stochastic model configured to execute a Monte Carlo algorithm that quantifies uncertainty associated with parameters characterizing a geothermal subsurface reservoir. The stochastic model can be further configured to estimate an amount of electrical power associated with the geothermal subsurface reservoir based on the parameters.
44.
METHODS FOR MANUFACTURE OF FLUORINATED PILLAR METAL-ORGANIC FRAMEWORK MATERIALS
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
SAUDI ARABIAN OIL COMPANY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Eddaoudi, Mohamed
Bhatt, Prashant
Jin, Tian
Abstract
A method for producing a fluorinated pillar metal-organic framework (MOF) materials is provided that avoids the need for high temperatures, and eliminates or substantially eliminates the need to use hydrofluoric acid. A reaction mixture comprising one or more sources of a metal Ma, niobium, fluorine and ligand in a solvent forms the fluorinated pillar MOF materials.
B01J 20/22 - Solid sorbent compositions or filter aid compositions; Sorbents for chromatography; Processes for preparing, regenerating or reactivating thereof comprising organic material
45.
SYSTEMS AND METHODS TO DETERMINE SEISMIC IMAGE BASED ON OPTIMAL TRANSPORT
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
He, Weiguang
Sui, Yuhan
Du, Yue
Abstract
Systems and methods are disclosed. The method includes obtaining observed seismic traces and initializing a velocity model for a subterranean region of interest. The method further includes iteratively updating the velocity model until a first convergence criterion is met. Iteratively updating the velocity model comprises initializing a convolution filter and, for each observed seismic trace, iteratively updating the convolution filter until a second convergence criterion is met and defining a trace objective function comprising the updated convolution filter. Iteratively updating the velocity model further comprises determining an objective function, wherein the objective function comprises a summation of the trace objective function for the observed seismic traces, determining an extremum of the objective function, and determining an updated velocity model based on the extremum. The method further still includes determining a seismic image of the subterranean region of interest using the observed seismic traces and the updated velocity model.
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Ma, Yue
Liu, Yujin
Liu, Hongwei
Abstract
A method for reducing coherent and random noise in seismic data is disclosed. The method includes, obtaining a plurality of time-space waveforms (300) and generating a plurality of overlapping time-space windows by dividing the plurality of time-space waveforms (310). For each overlapping time-space window, the method further includes determining a transformed window from the time-space window (320), determining a coherent noise window from the transformed window by performing a first soft thresholding based on a predetermined parameter range (330), determining a random noise window from the transformed window by performing a second soft thresholding (340), and determining a time-space filtered window based, at least in part, on subtracting the coherent noise window and the random noise window from the overlapping time-space window (350), determining a plurality of time-space filtered waveforms by assembling the time-space filtered window for each of the plurality of overlapping time-space windows (360). It also includes a non-transitory computer readable memory and a system.
G01V 1/28 - Processing seismic data, e.g. analysis, for interpretation, for correction
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A system includes production tubing (117), a Y-tool (202), and a downhole tool (200). The Y-tool (202) is installed within the production tubing (117) and splits the production tubing (117) into a first section (208), a second section (210), and a third section (212). The downhole tool (200) is configured to be run through a conduit (214) of the first section (208) of the production tubing (117) and configured to be installed within the production tubing (117). The downhole tool (200) includes a valve assembly (204), a seal stack (226), and a locking mechanism (228). The valve assembly (204) is configured to hydraulically connect either the second section (210) of the production tubing (117) or the third section (212) of production tubing (117) to the first section (208) of production tubing (117). The seal stack (226) is configured to mate with a seal bore (230) of the second section (210) of the production tubing (117). The locking mechanism (228) is configured to mate with a lock profile (232) of the second section (210) of the production tubing (117).
E21B 17/18 - Pipes provided with plural fluid passages
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
In some examples, a system can include a computer-readable medium storing computer-executable instructions and one or more processors communicatively coupled to a computer-readable medium storing computer-executable instructions, which, when executed by the one or more processors cause the one or processors to receive data of a fracking stage, determine a penetration gradient of the fracking stage based on the data, and classify the fracking stage based on the penetration gradient.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A system includes a vessel containing a crude oil inlet for introducing crude oil into the vessel; a fixed super-hydrophobic mesh subsystem comprising a fixed super-hydrophobic mesh; an inductor cup set system comprising at plurality of inductor cups, each of the plurality of inductor cups comprising a primary coil and a secondary coil, the inductor cups to determine an amount of water in the crude oil based on a comparison of the induced voltage between the primary coil and the secondary coil; a movable super-hydrophobic mesh subsystem comprising a super-hydrophobic mesh coupled to at least one stepper motor, the stepper motor to rotate the mesh by a predefined angle based on the comparison of the induced voltage determined by the inductor cups; and a metal grid subsystem comprising a metal grid electrically coupled to a transformer residing outside of the vessel, the metal grid to electrostatically dehydrate the crude oil.
C10G 45/08 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof in combination with chromium, molybdenum, or tungsten metals, or compounds thereof
C10G 45/10 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing platinum group metals or compounds thereof
C10G 69/06 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of thermal cracking in the absence of hydrogen
C10G 29/20 - Organic compounds not containing metal atoms
A stimulation tool (120) for dislodging material from a perforation formed through a tubular (110) disposed in a wellbore (102) includes a main body (202) formed at least in part from a material that is buoyant in a wellbore fluid (114), a ballast (206), a magnet (204), and a pressure pulse generator (210). The tool (120) is configured to descend downhole by force of gravity when the ballast (206) is attached and coupled, by the magnet (204), to an interior surface of the tubular (110) upon arrival at a downhole location proximate the perforation. When the tool (120) is coupled by the magnet to the interior of the tubular (110), the tool (120) transmits pressure pulses from the pressure pulse generator (210) into the perforation, thereby dislodging material from the perforation. The tool (120) de-couples from the interior surface and releases the ballast (206), thereby permitting the tool to ascend uphole, driven at least partially by a buoyant force exerted by the wellbore fluids (114).
E21B 37/00 - Methods or apparatus for cleaning boreholes or wells
E21B 47/09 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes
E21B 47/095 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/26 - Storing data down-hole, e.g. in a memory or on a record carrier
This disclosure relates to methods of detecting iron in a water injection system, such as a water injection system used in the oil and gas industry, using an optical siderophore-based biosensor. This disclosure also relates to methods of detecting corrosion using an optical siderophore-based biosensor.
An automatic salt-in-crude analysis system can include an electromagnetic circuit having a magnetic element with a first side and a second side separated by an air gap, a first winding wound around the first side, a voltage source connected to the first winding to apply a first voltage across the first winding, a second winding wound around the second side, and a voltage detector to detect a second voltage across the second winding, the second voltage induced in the second winding by the first voltage. While crude oil is in the air gap, a PLC can compare the second voltage and the first voltage, determine whether an amount of salt in the crude is greater than a threshold amount of salt by comparing the second voltage and the first voltage; and diluting crude oil in the oil tank if the amount of salt is above the threshold amount.
Systems and devices for igniting a gas to be flared include: a body having an inlet and an outlet, the body defining a channel extending between the inlet and the outlet; an igniter operable to generate a spark at the outlet of the body; an actuator disposed in the channel, the actuator configured to harvest energy when the gas to be flared flows from the inlet to the outlet through the channel and transfer the energy to the igniter.
F23G 7/08 - Methods or apparatus, e.g. incinerators, specially adapted for combustion of specific waste or low grade fuels, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases using flares, e.g. in stacks
F23Q 1/02 - Mechanical ignition using friction or shock effects
F23Q 9/04 - Ignition by a pilot flame without interlock with main fuel supply for upright burners, e.g. gas-cooker burners
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Li, Yupeng
Lu, Peng
Abstract
A method comprises importing an input depositional geological model of a formation, identifying one or more facies types as a location for one or more evaporation ponds and subsequent dolomite growth, defining dolomitization growth parameters of the one or more evaporation ponds, constructing a dolomite growth model, and integrating the dolomite growth model into an output depositional geological model of the formation including one or more dolomite geo-objects.
A method for assessing the maturity of data includes cataloging types of the data; developing key performance indicators for each data type; developing quality, governance, availability, and security rules for each data type; updating a database storing the data; and assessing quality, governance, availability, and security of the data based on the rules for each data type.
G06Q 10/0637 - Strategic management or analysis, e.g. setting a goal or target of an organisation; Planning actions based on goals; Analysis or evaluation of effectiveness of goals
G06Q 10/0639 - Performance analysis of employees; Performance analysis of enterprise or organisation operations
JAPAN COOPERATION CENTER FOR PERTOLEUM AND SUSTAINABLE ENERGY (Japan)
Inventor
Koseoglu, Omer Refa
Alzaid, Ali
Nakajima, Kazuki
Uchida, Koji
Matsumoto, Yusuke
Abstract
Hydrotreating catalyst material and/or hydrotreating catalyst particles are provided having at least two hydrotreating metal components and a chelating agent carried on a support. The support comprises an inorganic oxide binder and a post-framework modified ultra-stable Y-type (USY) zeolite in which a portion of aluminum atoms constituting a zeolite framework thereof is substituted with zirconium atoms and/or titanium atoms and/or hafnium atoms. The hydrotreating metal components form a metal complex via the chelating agent, and are carried on said support as chelating complex type II active sites.
C10G 45/08 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof in combination with chromium, molybdenum, or tungsten metals, or compounds thereof
B01J 29/08 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the faujasite type, e.g. type X or Y
B01J 29/16 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the faujasite type, e.g. type X or Y containing arsenic, antimony, bismuth, vanadium, niobium, tantalum, polonium, chromium, molybdenum, tungsten, manganese, technetium or rhenium
B01J 37/00 - Processes, in general, for preparing catalysts; Processes, in general, for activation of catalysts
B01J 37/02 - Impregnation, coating or precipitation
C10G 45/12 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing crystalline alumino-silicates, e.g. molecular sieves
58.
QUALITY CONTROL FOR GEO-SCIENCE DATA USING MACHINE LEARNING
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Li, Yupeng
Ma, Shouxiang
Luo, Maolin
Lu, Peng
Ayadiuno, Christopher
Abstract
A system and method for implementing a data quality control workflow for geo-science data. The system comprising one or more processors, operatively coupled to the memory, that execute the computer executable instructions. The computer executable instructions can be executed to implement a statistics analyzer configured to perform a statistical analysis on filtered geo-science dataset to detect a first set of outlier data points. The statistical analysis includes executing a univariate statistical analysis algorithm and a bivariate statistical analysis algorithm. Also, the statistics analyzer can be further configured to generate a cleaned dataset by removing the first set of outlier data points from the filtered geo-science dataset. Further, the computer executable instructions can be executed to implement a machine learning engine configured to perform a machine learning cluster analysis on the cleaned dataset via a Gaussian mixture model to identify a second set of outlier data points.
KING FAHD UNIVERSITY OF PETROLEUM AND MINERALS (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Jaseer, Ea
Barman, Samir
Villalta, Nestor Garcia
Khawaji, Motaz
Xu, Wei
Abstract
A catalyst system is disclosed. The catalyst system may include a pre-catalyst and a co-catalyst. The pre-catalyst includes one or more chromium compounds coordinated with a ligand. The co-catalyst includes one or more organoaluminum compounds, wherein: the ligand has a structure according to formula (I): (formula (I)). In formula (I), R1, R2, R3, and R466060) aryl, optionally substituted with one or more RS, wherein RS15015050) heterohydrocarbyl. In formula (I), R596046060) heteroaryl, optionally substituted with one or more RS, wherein RS15015050) heterohydrocarbyl, provided that R5 is not naphthyl or triptycenyl.
Methods for seismic imaging of a subterranean geological formation include receiving first acoustic impedance data, having a first resolution, associated with wells in a subsurface region. A system receives seismic data including second acoustic impedance data having a second resolution. The system performs a quality control process configured to identify a mismatch between the first acoustic impedance data and the second acoustic impedance data. The system resamples the second acoustic impedance data into a three-dimensional (3D) grid model. The system scales up the first acoustic impedance data into the 3D grid model. The system downscales the second acoustic impedance data controlled by the first acoustic impedance data in the 3D grid model. The system generates third acoustic impedance data representing fine-scale impedance data. The system extrapolates the fine-scale impedance into areas or regions having no seismic data coverage or poor seismic data coverage.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Mhanna, Mhanna
Arsalan, Muhammad
Farooq, Aamir
Abstract
A method (300) for water cut sensing in an oil-water flow involves obtaining a composite absorbance spectrum of the oil-water flow, obtaining a reference absorbance spectrum of a reference fluid, computing a slope (400) for data points associated with the composite absorbance spectrum of the oil-water flow vs corresponding data points associated with the reference absorbance spectrum of the known fluid, and based on the slope (400), determining the water cut of the oil-water flow.
G01N 21/3577 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing liquids, e.g. polluted water
G01N 21/39 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using tunable lasers
G01N 21/85 - Investigating moving fluids or granular solids
G01N 21/359 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light using near infrared light
62.
METHOD AND SYSTEM FOR WATER CUT SENSING IN AN OIL-WATER FLOW
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Mhanna, Mhanna
Arsalan, Muhammad
Sy, Mohamed
Farooq, Aamir
Abstract
A system (200, 250) for water cut sensing in an oil-water flow includes a laser-based spectroscopy sensor and a computer system (602). The laser-based spectroscopy sensor includes a first set of lasers that expose the oil-water flow to a first incident signal, a first photodetector that collects a first transmitted signal, the first transmitted signal being a component of the first incident signal transmitted through the oil-water flow, a second set of lasers that expose the oil-water flow to a second incident signal, and a second photodetector that collects a second transmitted signal, the second transmitted signal being a component of the second incident signal transmitted through the oil-water flow. The computer system (602) that calculates the water cut of the oil-water flow based on the first transmitted signal and the second transmitted signal.
G01N 21/3577 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing liquids, e.g. polluted water
G01N 21/359 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light using near infrared light
G01N 21/39 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using tunable lasers
G01N 21/85 - Investigating moving fluids or granular solids
Solidified nitrogen is placed at a downhole location within a wellbore formed in a subterranean formation. The solidified nitrogen is encapsulated by an emulsifying agent. The emulsifying agent is configured to dissolve in response to exposure to a downhole fluid. The solidified nitrogen encapsulated by the emulsifying agent is exposed to the downhole fluid at the downhole location within the wellbore, thereby dissolving the emulsifying agent and releasing the solidified nitrogen. The solidified nitrogen is allowed to sublimate into nitrogen gas within the wellbore, thereby reducing hydrostatic column in the wellbore. The downhole fluid is produced from the wellbore to a surface location.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
64.
HYPER-BRANCHED STIMULATION BY COMBINING RESERVOIR TUNNELING WITH EXTENDED NEEDLES
A system includes a wellbore (102), a primary tunnel (200), a jetting sub, a jetting needle, and a secondary tunnel (400). The wellbore (102) is drilled into a formation (104). The primary tunnel is formed from the wellbore (102). The jetting sub is disposed within the primary tunnel. The jetting needle is connected to the jetting sub. The jetting needle is configured to jut out from the jetting sub to penetrate the formation (104) when exposed to a pressure differential. The secondary tunnel (400) is formed from the primary tunnel (200) by a high-pressure j et of fluid exiting the jetting needle into the formation (104).
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Ali, Ola S.
Almajnouni, Khalid Ali
Sabate, Jorge Gascon
Shoinkhorova, Tuiana Bairovna
Gomez, Alberto Rodriguez
Dikhtiarenko, Alla
Abstract
Light olefins may be produced from hydrocarbons by a method including passing a hydrocarbon feed stream into one or more feed inlets of a reactor, using catalyst formulations or mixtures. Catalyst formulations may include multi-zeolite composite particles, or a mixture that is a physically mixed combination of separate particles of at least first composite particles of a first type of zeolite and second composite particles of a second type of zeolite. The reactor may include an upper reactor portion defining an upper reaction zone and a lower reactor portion defining a lower reaction zone. The catalyst may move in a generally downward direction through the upper reactor portion and the lower reactor portion, and the hydrocarbon feed stream may move in a generally upward direction through the lower reactor portion and upper reactor portion such that the hydrocarbon feed stream and the catalyst move with a counter-current orientation.
B01J 8/12 - Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with moving particles moved by gravity in a downward flow
B01J 8/38 - Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with fluidised particles according to "fluidised-bed" technique with fluidised bed containing a rotatable device or being subject to rotation
C10G 11/05 - Crystalline alumino-silicates, e.g. molecular sieves
C10G 11/16 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "moving bed" technique
C10G 51/02 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only plural serial stages only
A method for constructing docking stations (130a, 130b, 130c) for downhole robots (140a, 140b, 140c) is disclosed. The method includes determining locations and respective dimensions along a sidewall of a wellbore (120) for drilling tunnels (220a, 220b, 220c, 220d), constructing, based on the locations and respective dimensions, the tunnels (220a, 220b, 220c, 220d) extending from the sidewall of the wellbore (120), installing a downhole robot docking station (130a, 130b, 130c) in a first tunnel (220a, 220b, 220c) where the downhole robot docking station (130a, 130b, 130c) is disposed external to the wellbore (120), installing a power source in a second tunnel (220d) where the power source is disposed external to the wellbore (120), and connecting the downhole robot docking station (130a, 130b, 130c) and the power source via an electrical connection (130d) disposed along at least the sidewall of the wellbore (120).
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 41/00 - Equipment or details not covered by groups
E21B 43/30 - Specific pattern of wells, e.g. optimizing the spacing of wells
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 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
67.
PROCESSES FOR HYDROPROCESSING AND CRACKING CRUDE OIL
According to at least one aspect of the present disclosure, a process for processing a crude oil with an API between 30 and 35 degrees includes contacting the crude oil with one or more hydroprocessing catalysts to produce a hydroprocessed effluent. The hydroprocessed effluent is passed to an HS-FCC unit, where the hydroprocessed effluent is contacted with a cracking catalyst composition comprising nano-ZSM-5 zeolite and an ultrastable Y-type zeolite (USY zeolite) to form a cracked effluent comprising at least one product. The HS-FCC catalyst composition further comprises nano-ZSM-5 zeolite that has an average particle size of from 0.01 micrometers (μm) to 0.2 μm, USY zeolite impregnated with lanthanum, an alumina binder, colloidal silica, and a matrix material comprising Kaolin clay. The cracked effluent comprises at least olefins, aromatic compounds, or both.
C10G 11/05 - Crystalline alumino-silicates, e.g. molecular sieves
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
A test fixture (11) includes a cylindrical main body (27) extending in a longitudinal direction that receives a test piece (77). The cylindrical main body (27) includes a cylindrical screen filter (85) with a mesh surface that extends in a longitudinal axis coincident with an axis of the cylindrical main body (27). The mesh surface generates a filter cake when particle-entrained fluid is supplied through the mesh surface and the particulate is retained on the mesh surface. The cylindrical main body (27) also includes an offset shaft (81) that extends in the longitudinal direction along an offset axis that is offset from the axis of the cylindrical main body (27), and the test piece (77) extends through the offset shaft (81) and the interior of the cylindrical screen filter (85). The cylindrical main body (27) further includes a bearing (105) that decouples rotational motion of the offset shaft (81) from the end cap (29). Additionally, the test fixture (11) includes an actuator (23) that dislodges the test piece (77) from the filter cake, a computer that determines the dislodging force, and a reservoir pump (33) that pumps the particle-entrained fluid into the cylindrical screen filter (85). When the alignment wheel (83) is actuated, the offset shaft (81) forces the test piece (77) to move from a first position where a longitudinal axis of the test piece (77) is coincident to the longitudinal axis of the cylindrical screen filter (85) to a second position in which the axes are offset.
A solids trap module (100) for an electrical submersible pump (ESP) of a wellbore is provided. The module includes a solids buffer (120) and a fluid passage, the fluid passage having a first segment (122) configured to redirect a fluid in a first angular direction relative to an axial axis, and a second segment (124) configured to redirect at least a portion of the redirected fluid flow in a second angular direction different than the first angular direction. The first segment (122), the second segment (124), and the solids buffer (120) are configured to cooperate to cause settling of solids entrained by the fluid flowing through the solids trap module (100) during a period when the ESP does not operate and to re-entrain settled solids into the fluid flowing through the solids trap module (100) when the ESP is operating.
B01D 53/14 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
F23J 15/04 - Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material using washing fluids
71.
SYSTEMS AND PROCESSES FOR REFORMING A LIQUID HYDROCARBON FUEL
According to one or more other aspects of the present disclosure, a system for reforming a liquid hydrocarbon fuel includes a mixing zone with a fuel intake fluidly coupled to a liquid hydrocarbon fuel source and an oxygen-containing gas intake fluidly coupled to an oxygen-containing gas source. The mixing zone further includes at least one atomizing nozzle and a fuel distribution zone downstream the at least on atomizing nozzle. The system also includes a catalyst reaction zone downstream the mixing zone, including a monolith block having a plurality of flow channels defined by monolith walls and a reforming catalyst coated onto the monolith walls. The atomizing nozzle generates a plurality of droplets comprising the liquid hydrocarbon fuel suspended in oxygen-containing gas. The fuel distribution zone distributes the plurality of droplets to each of the plurality of flow channels to contact the reforming catalyst including N-hydroxyphthalimide.
B01J 19/24 - Stationary reactors without moving elements inside
F02D 19/06 - Controlling engines characterised by their use of non-liquid fuels, pluralities of fuels, or non-fuel substances added to the combustible mixtures peculiar to engines working with pluralities of fuels, e.g. alternatively with light and heavy fuel oil, other than engines indifferent to the fuel consumed
B01J 19/12 - Processes employing the direct application of electric or wave energy, or particle radiation; Apparatus therefor employing electromagnetic waves
73.
EXHAUST SYSTEM COMBUSTION FOR RAPID CATALYST HEATING
A motor system (100) includes an engine (104) having one or more cylinders, an electronic control unit (112), an exhaust treatment system (114) in fluid connection with and downstream of the one or more cylinders. The exhaust treatment system (114) includes an exhaust line (108), a combustion zone downstream, a combustion ignition source in the combustion zone, a catalyst downstream of an in thermal communication with the combustion zone. A method of heating a catalyst during an engine cold start and a method of initiating regular operating conditions of an engine (104) having one or more cylinders are also described.
F01N 3/06 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for extinguishing sparks
F02D 41/00 - Electrical control of supply of combustible mixture or its constituents
F02D 41/02 - Circuit arrangements for generating control signals
F02D 41/06 - Introducing corrections for particular operating conditions for engine starting or warming up
F01N 3/20 - Exhaust or silencing apparatus having means for purifying, rendering innocuous, or otherwise treating exhaust for rendering innocuous by thermal or catalytic conversion of noxious components of exhaust characterised by methods of operation; Control specially adapted for catalytic conversion
74.
CONVERTING STRANDED NATURAL GAS TO CARBON PARTICLES
A system and method for converting natural gas to carbon particles are provided. An exemplary method includes feeding the natural gas to a CNT reactor, forming an effluent stream including the carbon particles, separating the carbon particles from the effluent stream, forming a produced gas stream, combusting the produced gas stream to heat the CNT reactor, and providing the carbon particles.
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Yang, Yunlai
Li, Wei
Almarhoon, Maher I.
Abstract
A well site may include a wellbore extending into a subsurface formation and a drilling rig with a top drive and a drive shaft to rotate a drill string extending into the wellbore. The drill string includes a drill bit at an end distal to the drilling rig to cut rock of the subsurface formation to form the wellbore. Acoustic sensors may be positioned on the drive shaft, or the top drive, or the drill string. The acoustic sensors are configured to record and transmit drilling acoustic signals during a dummy drilling operation and a real drilling operation. A computer system may be in communication with the acoustic sensors. The computer system processes the drilling acoustic signals during the dummy drilling operation and the real drilling operation to minimize a drilling environmental effect by deducting a drilling environmental noise from the drilling acoustic signals to calculate clean drilling acoustic signals.
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
76.
USE OF PRESSURE WAVE RESONATORS IN DOWNHOLE OPERATIONS
A wellbore stimulation operation method includes conveying a downhole assembly into a wellbore including a production zone, the downhole assembly including one or more perforating guns and an pressure wave resonator, axially aligning the one or more perforating guns with the production zone, triggering operation of the one or more perforating guns and thereby creating a plurality of perforations in the production zone, axially aligning the pressure wave resonator with the plurality of perforations, actuating the pressure wave resonator and thereby emitting pressure waves that propagate radially outward and into the production zone, and removing debris from the plurality of perforations with the pressure waves.
According to at least one aspect of the present disclosure, a process for processing a crude oil with an API between 25 and 29 degrees includes contacting the crude oil with one or more hydroprocessing catalysts to produce a hydroprocessed effluent. The hydroprocessed effluent is passed to an HS-FCC unit, where the hydroprocessed effluent is contacted with a cracking catalyst composition comprising nano-ZSM-5 zeolite and an ultrastable Y-type zeolite (USY zeolite) to form a cracked effluent comprising at least one product. The HS-FCC catalyst composition further comprises nano-ZSM-5 zeolite that has an average particle size of from 0.01 micrometers (μm) to 0.2 μm, USY zeolite impregnated with lanthanum, an alumina binder, colloidal silica, and a matrix material comprising Kaolin clay. The cracked effluent comprises at least olefins, aromatic compounds, or both.
C10G 11/05 - Crystalline alumino-silicates, e.g. molecular sieves
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
78.
POLYMERIC RED MUD-BASED KILLING FLUID AND USES THEREOF
Disclosed are methods, systems, and computer-readable medium to perform operations including: obtaining production data about the well; generating a simulated average reservoir pressure at the subsurface region that includes the well; computing a difference between an average reservoir pressure obtained from the production data and the simulated average reservoir pressure; determining, based on the computed difference, a performance deviation with reference to a particular area of the subsurface region that includes the well; comparing the performance deviation to a predetermined threshold value that represents an acceptable tolerance for variance in performance of the well; and triggering, when the performance deviation exceeds the predetermined threshold value, a particular type of automated response comprising an action that addresses the variance in performance of the well.
E21B 41/00 - Equipment or details not covered by groups
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Disclosed are methods, systems, and computer-readable medium to perform operations including: obtaining surface production data of wells in the gas production system; generating, using a well simulation module and a surface network module, predictions about a plurality of conditions in the gas production system; computing a difference between measured conditions obtained from the production data and predicted conditions obtained from the predictions about the plurality of conditions; determining, based on the computed difference, a performance deviation in the gas production system; comparing the performance deviation to a predetermined threshold value that represents an acceptable tolerance for variance in performance of the gas production system; and triggering, when the performance deviation exceeds the predetermined threshold value, a particular type of automated response comprising an action that addresses the variance in performance of the gas production system.
An integrated carbon dioxide methanation system and a method of making methane are provided. An exemplary method of making methane includes generating electricity using renewable energy sources, obtaining carbon dioxide from biogas processing or post combustion carbon capture, obtaining hydrogen from water splitting or gasification of biomass, combining the carbon dioxide and the hydrogen to form a mixture, and reacting the mixture with a nickel catalyst made using atomic layer deposition to yield methane.
C07C 1/12 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon from oxides of carbon from carbon dioxide with hydrogen
Disclosed are methods, systems, and computer-readable medium to perform operations including: calculating a rate of flow change per minute in a pipeline of the hydrocarbon production system; determining that the rate of flow change is at least ten percent greater than a predetermined flow change threshold; based on a difference between the rate of flow change and the predetermined flow change threshold, triggering one of a high alarm workflow, a high-high alarm workflow, and a high-high-high alarm workflow; detecting, using the triggered one of the high alarm workflow, the high-high alarm workflow, and the high-high-high alarm workflow, a potential or actual break in the pipeline; and in response, performing a corrective action to avoid the potential break or mitigate the actual break in the pipeline.
The present disclosure is directed to systems and methods for reforming a hydrocarbon fuel to increase the cetane value of the hydrocarbon fuel. The system includes a microstatic mixer and a microchannel reactor downstream of the microstatic mixer. The microchannel reactor includes a microchannel with an NHPI catalyst coated onto the walls of the microchannel. A hydrocarbon fuel and an oxygen-containing gas are combined and mixed in the microstatic mixer to produce a combined stream and the combined stream is passed through the microchannel. The microchannel reactor includes a heat transfer system. The hydrocarbon fuel and oxygencontaining gas are contacted in the microchannel in the presence of the catalyst at a reaction temperature sufficient to produce a reformed hydrocarbon fuel having a cetane value greater than a cetane value of the starting hydrocarbon fuel.
B01J 19/24 - Stationary reactors without moving elements inside
F02D 19/06 - Controlling engines characterised by their use of non-liquid fuels, pluralities of fuels, or non-fuel substances added to the combustible mixtures peculiar to engines working with pluralities of fuels, e.g. alternatively with light and heavy fuel oil, other than engines indifferent to the fuel consumed
A drilling system measures a fluid level in a wellbore. The drilling system may include a drill pipe (216) and a sensor sleeve (302) attached to the drill pipe (216). The sensor sleeve (302) may include a transmitter that transmits a sensing signal (506) in a direction of a fluid in the wellbore, a receiver that receives the sensing signal (506) after the sensing signal (506) is reflected on a surface of the fluid, and a repeater (800) that determines a distance between the sensor sleeve (302) and the fluid level from the transmitted and received sensing signal (506). The fluid level in the wellbore may be calculated using the distance determined by the repeater (800) and a distance between the sensor sleeve (302) and a surface of the wellbore.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
22 from the exhaust gas to form a first feed, a second portion of the natural gas forms a second feed. The system also includes a bi-reforming reactor comprising a bi-reforming catalyst to react the first feed and the second feed to form hydrogen and carbon monoxide, and a dimethyl ether (DME) reactor comprising a DME catalyst to form DME from the hydrogen and carbon monoxide.
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
C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
Systems and methods include a computer-implemented method for analyzing rock samples. Rock and oil electromagnetic baselines are determined for rock samples in at least a section of an electromagnetic spectrum ranging from ultraviolet to long terahertz radiation. An aging process is conducted on each rock sample, initially starting with the rock and oil electromagnetic baselines. The aging process is repeated using spectrometry on the rock sample and measured wettabilities of the rock sample until changes in spectra are less than a predetermined threshold. Aging information including the spectra and wettabilities are stored in a machine learning database. Spectra are obtained from an unknown rock sample. The spectra are mapped to clusters in the machine learning database. Wettability ranges are determined for the unknown rock sample based on a mapping of the spectra of the unknown rock sample to clusters in the machine learning database.
G01N 21/3563 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing solids; Preparation of samples therefor
A method includes providing a plurality of prefabricated parts (S302) for assembly, where the plurality of prefabricated parts (S302) comprises one or more rubber mats (102, 104, 204) and a central core (106). The method also includes preparing one or more external surfaces of the central core (106), applying a sealer to the one or more external surfaces of the central core (106), applying a bonding agent primer and a top coat to the one or more external surfaces of the central core (106), and pressing the one or more rubber mats to the one or more external surfaces of the central core (106). The method further includes applying a constant pressure to the one or more rubber mats and the central core (106), where a combination of the one or more rubber mats and the central core (106) forms a blast and ballistic resistance wall (100).
Systems and methods include a computer-implemented method for predicting temperatures. Temperature data corresponding to historical drilling operations of a well is collected and stored in a database. The database is split into a training dataset and an evaluation dataset. Space-time-temperature probability models are generated using the training dataset. The space-time-temperature probability models are trained using the evaluation dataset. The space-time-temperature probability models are evaluated to ensure a performance level above a model accuracy threshold. A predicted temperature profile for a new well is generated using the space-time-temperature probability models.
A testing system (100) includes a main wellbore (102), at least one injection tunnel (130) and production tunnel (140), a monitoring system (150) including at least one sensor (152), and a recovering tube (160). The injection and production tunnels (130, 140) are parallel with each other and extend perpendicularly from the main wellbore (102). The method for conducting in-situ oil recovery sweep testing includes introducing an injection fluid into a main wellbore (102) and at least one injection tunnel (130), monitoring conditions of the at least one production tunnel (140), and collecting produced fluid from the production tunnel (140) with a recovering tube (160). A method for conducting sequential in-situ oil recovery sweep testing includes locating a recovering tube (160) in a target production tunnel (170) and conducting a sweeping process. The sweeping process includes introducing an injection fluid into an injection tunnel (130), monitoring conditions of the target production tunnel (170), collecting a produced fluid from the target production tunnel (170), isolating the target production tunnel (170), and repeating.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Almajnouni, Khalid Ali
Ali, Ola S.
Sabate, Jorge Gascon
Al Aslani, Isa
Alabbad, Shatha Ali
Abstract
Light olefins may be produced from hydrocarbons by a method including passing a hydrocarbon feed stream into one or more feed inlets of a reactor, with one or more co-feeds of steam, a recycle stream or oxygenates. The reactor may include an upper reactor portion defining an upper reaction zone and a lower reactor portion defining a lower reaction zone. The catalyst may move in a generally downward direction through the upper reactor portion and the lower reactor portion, and the hydrocarbon feed stream may move in a generally upward direction through the lower reactor portion and upper reactor portion such that the hydrocarbon feed stream and the catalyst move with a counter-current orientation. Contacting the catalyst with the hydrocarbon feed stream may crack one or more components of the hydrocarbon feed stream and form a hydrocarbon product stream.
C10G 11/14 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
An apparatus (100) configured be used to separate drill cuttings from drilling fluid. The apparatus includes a receptacle (102), a screen (104), acoustic transducers (106), and a collection pan (108). The receptacle (102) is configured to receive a mixture (101) of the drill cuttings and the drilling fluid. The receptacle (102) is configured to distribute the mixture (101) of the drill cuttings and the drilling fluid across a first end (104a) of the screen (104). The acoustic transducers (106) are attached to the screen (104). The acoustic transducers (106) are configured to generate acoustic vibrations in a range of frequencies. The generated acoustic vibrations facilitate travel of the mixture (101) across the screen (104) and cause the drill cuttings to separate as the mixture travels across the screen (104). The collection pan (108) is positioned at a second end (104b) of the screen (104) opposite the receptacle (102). The collection pan (108) is configured to receive at least a portion of the drill cuttings that have travelled across the screen (104).
B07B 1/46 - Constructional details of screens in general; Cleaning or heating of screens
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B01D 33/03 - Filters with filtering elements which move during the filtering operation with translationally moving filtering elements, e.g. pistons with vibrating filter elements
A hydrocarbon feed stream is exposed to heat in an absence of oxygen to the convert the hydrocarbon feed stream into a solids stream and a gas stream. The gas stream is separated into an exhaust gas stream and hydrogen. The carbon is separated from the solids stream as a carbon stream. Electrolysis is performed on a water stream to produce an oxygen stream and hydrogen. The oxygen and a portion of the carbon are combined to generate power and a carbon dioxide stream. At least a portion of the carbon stream, cement, and water are mixed to form a concrete mixture. The concrete mixture can be used to produce ready-mix concrete and precast concrete. Carbon dioxide used for curing the concrete can be sourced from the carbon dioxide stream produced by power generation.
C01B 3/24 - Production of hydrogen or of gaseous mixtures containing hydrogen by decomposition of gaseous or liquid organic compounds of hydrocarbons
C04B 40/02 - Selection of the hardening environment
C25B 1/04 - Hydrogen or oxygen by electrolysis of water
C04B 22/10 - Acids or salts thereof containing carbon in the anion, e.g. carbonates
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
94.
SUBSURFACE ANNULAR PRESSURE MANAGEMENT SYSTEM - A METHOD AND APPARATUS FOR DYNAMICALLY VARYING THE ANNULAR WELL PRESSURE
A downhole tool (300) includes a choke (308), a controller (316), a communication and power element, instrumentation (318, 320), and a stabilizer (312, 322). The choke (308) is configured to vary an annular well pressure. The choke (308) includes an expandable element (326) having an expanded position, an expanding position, and an unexpanded position. The controller (316) is connected to the choke (308) and is configured to place the choke (308) in the expanded position, the expanding position, and the unexpanded position. The communication and power element is electronically connected to the controller (316). Power and instructions are sent to the controller (316) from the communication and power element. The instrumentation (318, 320) is electronically connected to the communication and power element. The instrumentation (318, 320) comprises sensors configured to obtain downhole data and the downhole data is sent to the communication and power element. The stabilizer (312, 322) is configured to centralize the choke (308) within the casing string (302).
An intelligent drilling system (200a) is disclosed. The intelligent drilling system (200a) includes an inner drill pipe (201a) adapted to rotate around a longitudinal axis in a transversal plane of a wellbore to advance a drill bit (205) during a drilling operation, an external drill string shield (202) surrounding the inner drill pipe (201) and coupled to the inner drill pipe (201) via at least one bearing system (201, 211), the at least one bearing system (201, 211) adapted to decouple the external drill string shield (202) from a rotational motion of the inner drill pipe (201) in the transversal plane such that the external drill string shield (202) remains substantially stationary during the drilling operation, and an in-situ sensing system (203) disposed on an interior of the external drill string shield (202) to measure at least one downhole parameter of the wellbore.
E21B 17/18 - Pipes provided with plural fluid passages
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 21/12 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems
E21B 4/00 - Drives for drilling, used in the borehole
Systems and methods of predicting reservoir quality can include measuring properties of a subsurface reservoir. Based on the measured properties of the subsurface reservoir; a modeling grid and domain representing a sediment textural framework of a subsurface reservoir are initialized. Deposition of sediments during the time period is predicted using a depositional model. The modeling grid and domain are updated based on the predicted deposition. The modeling grid and domain is transferred from the depositional model to a diagenetic model. The sediment textural framework of the area's subsurface is updated using the diagenetic model to simulate physical and chemical changes to deposited sediments during the time period. The modeling grid and domain is stored and a test well can be drilled based on the modeling grid and domain.
Methods for synthesizing a nano-sized zeolite beta are described. The method may include mixing alumina and tetraethylammonium hydroxide to form an aluminum solution; mixing silica, additional TEAOH, and water to form a silica slurry; and adding the aluminum solution into the silica slurry and mixing to form an aluminosilicate gel. The method may further include transferring the aluminosilicate gel to an autoclave operated at 120℃ to 160℃ for 2 to 4 days at a rotational speed of 60 to 100 rotations per minute to form a zeolite precursor colloid; washing the zeolite precursor colloid with water to form a washed colloid; drying the washed colloid at 80℃ to 150℃ for 6 to 24 hours to form a zeolite precursor; and calcining the zeolite precursor at 400℃ to 650℃ for 2 to 8 hours to form the nano-sized zeolite beta.
C01B 39/48 - Other types characterised by their X-ray diffraction pattern and their defined composition using at least one organic template directing agent
98.
METHOD FOR SYNTHESIZING MESOPOROUS NANO-SIZED ZEOLITE BETA
Methods for synthesizing a mesoporous nano-sized zeolite beta are described. The method includes preparing an aqueous hexadecyltrimethylammonium bromide (CTAB) solution and adding nano-sized zeolite particles having a BEA framework type, a particle size of less than or equal to 100 nm, and a microporous framework with a plurality of micropores having diameters of less than or equal to 2 nm to form a second solution. The second solution does not include a base. The method further includes transferring the second solution to an autoclave operated at 25°C to 200°C for 3 to 24 hours to form a colloid; washing the colloid with water to form a washed colloid; drying the washed colloid at 100°C to 200°C for 4 to 24 hours to form a zeolite precursor; and calcining the zeolite precursor at 250°C to 600°C for 1 to 8 hours to form the mesoporous nano-sized zeolite beta.
C01B 39/02 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof; Direct preparation thereof; Preparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactants; After-treatment thereof
99.
METHOD FOR SYNTHESIZING MESOPOROUS NANO-SIZED ULTRA-STABLE Y ZEOLITE
223222O. The method further includes heating the hydrogel to an autoclave to form a zeolite precursor which is filtered and washed to form a nano-sized Y zeolite. Further the method includes combining the nano-sized Y zeolite with water to form a nano-sized Y zeolite slurry mixture and then adding a 0.1 to 2.0 M aqueous solution of ammonium hexafluorosilicate to form a dealuminated solution. Finally the method includes filtering and washing the dealuminated solution with water to form an ultra-stable Y zeolite precursor, drying the ultra-stable Y zeolite precursor, and calcining the dried zeolite precursor to form the nano-sized ultra-stable Y zeolite.
C01B 39/02 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof; Direct preparation thereof; Preparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactants; After-treatment thereof
233 molar ratio of less than 5.2 with water to form a microporous Y zeolite slurry and heating the microporous Y zeolite slurry to 30℃ to 100℃ to form a heated microporous Y zeolite slurry. Further the method includes adding a 0.1M to 2.0M ammonium hexafluorosilicate solution and a 0.1M to 2.0M ammonium hydroxide solution in a drop-wise manner, either sequentially or simultaneously, to the heated microporous Y zeolite slurry to form a treated zeolite solution and holding the treated zeolite solution at 50℃ to 100℃. Finally the method includes filtering and washing the dealuminated solution with water to form an ultra-stable Y zeolite precursor, drying the ultra-stable Y zeolite precursor, and calcining the dried zeolite precursor to form the nano-sized ultra-stable Y zeolite.
C01B 39/02 - Crystalline aluminosilicate zeolites; Isomorphous compounds thereof; Direct preparation thereof; Preparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactants; After-treatment thereof
patents
