Example computer-implemented methods, media, and systems for identification and characterization of geologic features in carbonate reservoir are disclosed. One example computer-implemented method includes obtaining multiple core sample images of a carbonate reservoir. The multiple core sample images are labeled using multiple feature classes, where the multiple feature classes include at least one of a vug or fracture. Multiple image patches are generated using the labeled plurality of core sample images. A machine learning model is applied to the multiple image patches to identify one or more vugs or fractures in the multiple core sample images. At least one of porosity or permeability of the carbonate reservoir is predicted using the identified one or more vugs or fractures in the multiple core sample images.
A method to detect hydraulic leaks in unmanned locations includes obtaining a first pressure reading, starting a header pressure pump if the first pressure reading meets a low-level threshold; determining if production valves were opened; terminating operation of the header pressure pump if second pressure reading meets a high-level threshold; and incrementing a pump counter by one. The method includes storing a first snapshot of a fluid level when the pump counter is greater than a pump cycle threshold and starting a predetermined time interval following storing of the first snapshot; storing a second snapshot of the fluid level after the predetermined time interval expires and calculating a difference between the second snapshot and the first snapshot; initiating an alarm when the difference is greater than an allowable leak threshold and resetting the pump counter at a specific time of day.
This disclosure describes systems and methods for determining spatial distributions of petrophysical properties in a subsurface formation. A method includes obtaining input data including petrophysical data, geophysical data and geological data of the subsurface formation; selecting input features from the input data; forming a training dataset including the input features and corresponding labeled data representing a target petrophysical property of the subsurface formation; training, using the training dataset, an ensemble machine learning model; and determining a spatial distribution of the target petrophysical property based on the trained ensemble machine learning model.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 99/00 - Subject matter not provided for in other groups of this subclass
Drilling fluids may comprise a base fluid, wherein the base fluid is an invert emulsion comprising an oil and water; one or more additives; and a viscosifier comprising 2-dodecenyl succinic acid. Methods for using a drilling fluid may comprise operating a drill in a wellbore in the presence of a drilling fluid comprising a base fluid, wherein the base fluid is an invert emulsion comprising an oil and water; one or more additives; and a viscosifier comprising 2-dodecenyl succinic acid.
Systems for cooling a steelmaking plant can include a heat recovery unit with a gas inlet receiving flue gases from production processes of the steelmaking plant. A wastewater treatment unit has an inlet receiving waste water from the production processes of the steelmaking plant and a clean water outlet hydraulically connected to a cooling water inlet of the heat recovery unit. An absorption cooling unit has an inlet hydraulically connected to a hot water discharge of the heat recovery unit.
F27D 9/00 - Cooling of furnaces or of charges therein
C02F 1/28 - Treatment of water, waste water, or sewage by sorption
C02F 103/16 - Nature of the water, waste water, sewage or sludge to be treated from metallurgical processes, i.e. from the production, refining or treatment of metals, e.g. galvanic wastes
F25B 15/06 - Sorption machines, plants or systems, operating continuously, e.g. absorption type without inert gas the refrigerant being water vapour evaporated from a salt solution, e.g. lithium bromide
6.
SYSTEM AND METHOD FOR SECURE DATA EXCHANGE BETWEEN OPERATIONAL TECHNOLOGY SYSTEMS AND EXTERNAL NETWORKS IN AIR-GAP ARCHITECTURE ENVIRONMENT
A system for secure data exchange between an operational technology network and an external information technology network separated by an air gap. The system includes a handheld computing device, a first central station coupled to the external information technology network and a receptacle for detachable coupling to the handheld computing device. The system also includes a second central station coupled to the operational technology network and a receptacle for detachable coupling to the handheld computing device. The system manages secure file transfers between the first central station and the second central station in which a file is uploaded to the detachable handheld device, and in which the handheld device is detachable and moveable from the first central station to the second central station or vice versa. Thereafter, the handheld device is attachable to the central station to which it has been moved to enable secure downloading of the file.
H04L 67/12 - Protocols specially adapted for proprietary or special-purpose networking environments, e.g. medical networks, sensor networks, networks in vehicles or remote metering networks
7.
QUANTIFYING ZONAL FLOW IN MULTI-LATERAL WELLS VIA TAGGANTS OF FLUIDS
A method of quantifying zonal flow in a multi-lateral well is described. A first taggant is flowed to a first lateral, and a second taggant is flowed to a second lateral. A first produced fluid that includes the first taggant is flowed from the first lateral into a production tubing. A second produced fluid that includes the second taggant is flowed from the second lateral into the production tubing. A produced stream including the first produced fluid and the second produced fluid is flowed uphole through the production tubing. An amount of the first taggant and an amount of the second taggant in the produced stream are measured. Production of fluid from the multi-lateral well proceeds without ceasing throughout the method.
A method for recommending content resources to individuals in an organization. The method includes obtaining a content repository containing one or more content resources, obtaining a first individual data for a first individual and determining, from the first individual data, a first skillset for the first individual, the first skillset including a first skill, the first skill including a first metric including a first description and first value. The method further includes determining a first score for the first skill based on the first individual data and the first metric, obtaining a content map that associates each skill in the first skillset to at least one content resource of the content repository and recommending a first content resource from the content repository for the first individual based on the first score and the content map.
A gas-oil separation plant (GOSP) system includes a crude inlet line extending to a separation vessel where a sour gas stream may be separated from an inlet fluid stream. The GOSP system provides an H2S membrane system where the sour gas stream may be directed for separation of H2S and an electrolyzer where H2 may be separated from the H2S. The GOSP system also includes a combustion gas turbine where an exhaust containing CO2 is produced and a CO2 membrane system where the CO2 may be separated from the exhaust. The H2 and CO2 may be combined and reacted in a Sabatier reactor to produce CH4 and H2O. The CH4 may be used to fuel the combustion gas turbine and the H2O may be directed to a steam head for use in other processes. Additionally, a sweetened gas stream having the H2S removed may be exported by the GOSP system.
C10G 31/09 - Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by filtration
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
C07C 7/10 - Purification, separation or stabilisation of hydrocarbonsUse of additives by extraction, i.e. purification or separation of liquid hydrocarbons with the aid of liquids
Systems and methods for determining caprock integrity for geological sequestration of CO2, such as in above saline aquifers. The testing system for performing the method includes a core container in fluid communication with an upstream reservoir and an upstream pump, further in fluid communication with a downstream liquid reservoir and a downstream liquid pump, and further in fluid communication with a downstream gas reservoir and a downstream gas pump. The method includes determining transient hydraulic conductivity and hydraulic gradient of a caprock core sample using the testing system based on non-Darcy flow.
A computer-assisted method to monitor soil porosity at a field study site using a portable apparatus, the method including: acquiring a soil sample using a first container; recording a first measurement of a mass and a volume of the soil sample; adding the soil sample to a second container until the soil sample is added in entirety, wherein the second container is pre-filled with a fluid medium, wherein the soil sample is added to the second container without causing soil clustering, and wherein a second measurement of a mass of the second container with the fluid medium is recorded; recording a third measurement of a mass of the second container with the soil sample fully immersed in the fluid medium; calculating a porosity of the soil sample based on the first, second, and third measurements; and providing, at the field study site, the calculated porosity of the soil sample.
G01N 1/44 - Sample treatment involving radiation, e.g. heat
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 15/00 - Investigating characteristics of particlesInvestigating permeability, pore-volume or surface-area of porous materials
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
G01N 19/10 - Measuring moisture content, e.g. by measuring change in length of hygroscopic filamentHygrometers
12.
METHODS OF RECOVERING BARIUM FROM PRODUCED WATER TO REMOVE SULFATES IN SEAWATER FOR OILFIELD APPLICATIONS
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Hou, Jian
Huang, Tianpiang
Alghunaimi, Fahd Ibrahim
Aljuryyed, Norah W.
Abstract
A method for removing sulfates from seawater by immersing a barium adsorbent into produced water to adsorb the barium ions from the produced water. The adsorbent is combined with an acidic solution that pulls the barium ions into the acidic solution. The acidic solution containing barium ions is combined with seawater to precipitate the sulfate as barium sulfate (BaSO4).
B01J 20/28 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof characterised by their form or physical properties
C02F 1/28 - Treatment of water, waste water, or sewage by sorption
C02F 1/66 - Treatment of water, waste water, or sewage by neutralisationTreatment of water, waste water, or sewage pH adjustment
Embodiments herein are directed to a method for forming a solidified fluid barrier in a wellhead including: injecting a wellhead sealing composition into a first flow line, a second flow line, a crown valve, or combinations thereof of the wellhead, the wellhead including at least a wellbore casing, a master valve, a fluid chamber, a first wing valve, a second wing valve, and a crown valve; pumping the wellhead sealing composition including a cyclodextrin, water, and an azaarene into the fluid chamber of the wellhead; and heating the wellhead sealing composition to solidify the wellhead sealing composition in the fluid chamber. Further embodiments herein are directed to a wellhead for a subsurface well including a wellbore casing, a master valve, a fluid chamber including a solidified fluid barrier including alpha-cyclodextrin, water, and 4-methylpyridine, a first wing valve, a second wing valve, and a crown valve.
C09K 8/44 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing organic binders only
A method includes performing, on a core sample obtained from a reservoir and positioned in a permeability measurement assembly that includes a flow inlet, a permeability operation by flowing a test fluid from the flow inlet and into the core sample and changing an effective stress acting on the core sample. The method also includes determining a natural logarithm of permeability of the core sample as a function of the effective stress, and determining, as a function of the natural logarithm of permeability of the core sample, an initial pore pressure of the reservoir.
A method involves mixing metallic particles and a liquefied polymer to form a mixture, placing the mixture within a mold, placing a magnet in the vicinity of the mixture within the mold, thereby causing the metallic particles to position themselves in a self-assembly formation within the mixture in response to a magnetic field generated by the magnet, and solidifying the liquefied polymer, such that a polymer matrix is formed. The metallic particles are distributed and secured in the self-assembly formation throughout the polymer matrix, thereby forming a ballast for an untethered downhole tool configured to be lowered into a well formed in a subterranean formation. The polymer matrix is configured to dissolve in response to being exposed to downhole fluid within the well at specified downhole conditions.
A method of treating a sorbent having a species sorbed thereto includes reacting a first reactant and a second reactant to generate heat, and heating the sorbent with the generated heat to desorb the sorbed species form the sorbent. The first reactant includes a molecule having the same chemical identity as the sorbed species. Systems for carrying out such methods are provided.
B01D 53/04 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography with stationary adsorbents
B01D 53/08 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography with moving adsorbents according to the "moving bed" method
B01D 53/12 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography with moving adsorbents with dispersed adsorbents according to the "fluidised technique"
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
C07C 273/04 - Preparation of urea or its derivatives, i.e. compounds containing any of the groups the nitrogen atoms not being part of nitro or nitroso groups of urea, its salts, complexes or addition compounds from carbon dioxide and ammonia
17.
HIGH PERFORMANCE FRACTURING FOAM AND RELATED METHODS
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Zhang, Xuan
Huang, Tianping
Harbi, Bader G.
Karadkar, Prasad B.
Han, Ming
Abstract
Disclosed is a foam that may be used in subterranean formations. The foam composition may include a betaine surfactant; an associative polymer; a crosslinker comprising a metal or a borate; a thermal stabilizer comprising a sulfur thermal stabilizer or a polar alcohol; and a gas. Also disclosed is a method comprising providing a base fluid composition comprising: a betaine surfactant; an associative polymer; a crosslinker comprising a metal or a borate; and a thermal stabilizer comprising a sulfur thermal stabilizer or a polar alcohol; mixing it with a gas; and discharging the mixture into a subterranean formation.
A method (1300) that includes disposing (1310) a packer and an ESP inside a production tubing bore. The ESP includes a pump, a discharge, a shroud, and a bypass sub coupled to the shroud. The shroud includes a closed end coupled to a base of the pump. The packer, coupled to an outer surface of the shroud, is located downstream of the bypass sub. The method includes circulating (1320) liquids from the pumping base through the discharge to a shroud open end downstream of the packer thereby sealing (1330) the packer between the outer surface and the production tubing bore. The method includes pumping (1340), using the pump device, the liquids through the production tubing using the bypass sub and performing (1350) a production operation using the wellhead assembly to obtain an amount of gas production.
A method includes providing an electrical submersible pump assembly with a pump, an intake (424), shroud base flanges (402), a protector (420), and a motor (416). The method includes coupling the shroud base flanges (402) to an intake downhole end (307) using fasteners (421) and a set of protector top bolt holes (422). The method includes locating a closed end (44) of an inverted shroud (442) between the intake (424) and the protector (420). The inverted shroud (442) includes a shroud base (444) on the closed end, and an opposite open end that is open toward the packer (40). The method includes coupling the inverted shroud (442) to the shroud base flanges (402). The packer (40) is located uphole of the opposite open end at a distance causing a mixing of a gas pocket with the well fluid to form a combined gas and liquid mixture and directing the combined gas and liquid mixture in a direction toward the intake (424).
Methods and systems are disclosed. The method may include installing a fluid detection sensor (618a-e) in a first lateral extension (610a) from a primary wellbore (116), establishing a fluid conduit (616) from a well-head to a second lateral extension (610b) from the primary wellbore (116), pumping a marker fluid through the fluid conduit (616) from the well-head to the second lateral extension (610b) and into the subterranean region of interest. The method further includes detecting, using the fluid detection sensor (618a-e), the marker fluid in the first lateral extension (610a), wherein the marker fluid in the first lateral extension (610a) has flowed from the second lateral extension (610b) through the subterranean region of interest and determining the fluid flow characteristic of the subterranean region of interest based, at least in part, on the detected marker fluid.
Techniques for updating hydrocarbon parameters include identifying well data associated with wells formed in subterranean formations of a hydrocarbon reservoir; determining a data density value for each well; assigning each well into a pressure grouping based on a wellbore pressure similarity of the well relative to an initial pattern well; generating a two-dimensional (2D) model of the hydrocarbon reservoir; converting the 2D model into a three-dimensional (3D) model of the hydrocarbon reservoir; and updating a permeability or a porosity associated with a grid cell of the 3D model.
A method of introducing cavitation downhole includes creating cavitation nuclei, introducing cavitation nuclei to a drilling fluid, delivering the drilling fluid downhole, and activating an acoustic source downhole. A method of preventing lost circulation includes introducing cavitation nuclei downhole, introducing lost circulation materials downhole where the lost circulation materials include a resin and microcapsules of a crosslinking agent, activating an acoustic source which may induce cavitation; and rupturing the microcapsules of the crosslinking agent to prevent lost circulation.
E21B 21/14 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using liquids and gases, e.g. foams
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
A system for secure data exchange between an operational technology network and an external information technology network separated by an air gap. The system includes a handheld computing device, a first central station coupled to the external information technology network and a receptacle for detachable coupling to the handheld computing device. The system also includes a second central station coupled to the operational technology network and a receptacle for detachable coupling to the handheld computing device. The system manages secure file transfers between the first central station and the second central station in which a file is uploaded to the detachable handheld device, and in which the handheld device is detachable and moveable from the first central station to the second central station or vice versa. Thereafter, the handheld device is attachable to the central station to which it has been moved to enable secure downloading of the file.
Methods and systems including introducing a treatment fluid into a subterranean formation wellbore. The treatment fluid includes an aqueous base fluid; nitrogen-containing waste plastic; and carbon dioxide. The nitrogen-containing waste plastic is hydrolyzed in the aqueous base fluid under conditions in the subterranean formation wellbore, thereby forming hydrolysis reaction products. The hydrolysis reaction products and the carbon dioxide are reacted in the subterranean formation wellbore.
A method of preparing aluminum oxide includes calcining a spent Claus catalyst, wherein the catalyst includes at least 75% alumina compounds.
A method of preparing aluminum oxide includes calcining a spent Claus catalyst, wherein the catalyst includes at least 75% alumina compounds.
A method of preparing aluminum oxide includes calcining a mixture of alumina compounds, wherein the alumina compounds comprise bochmite, γ-aluminum oxide, corundum, and gibbsite.
King Abdullah University of Science and Technology (Saudi Arabia)
Inventor
He, Xupeng
Alsinan, Marwah M.
Li, Yiteng
Zhang, Zhen
Kwak, Hyung Tae
Hoteit, Hussein
Rao, Xiang
Abstract
A method includes modeling a reservoir using a lab scale set of models and a field scale set of models. The reservoir is modeled using the lab scale set of models by scanning a sample of the reservoir into the lab scale set of models to create modeled fractures, estimating hydraulic properties of the modeled fractures, estimating multi-phase dynamic properties of the modeled fractures, and determining characteristics of a flow regime of a fluid flowing through the modeled fractures. The reservoir is modeled using the field scale set of models by modeling a discrete fracture network of the reservoir, upscaling the discrete fracture network, and calibrating the discrete fracture network. An enhanced oil recovery operation is designed and performed on the reservoir using the calibrated discrete fracture network.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 43/17 - Interconnecting two or more wells by fracturing or otherwise attacking the formation
Methods for reducing scale deposition are provided. An exemplary method for reducing scale in an oilfield facility includes contacting a production surface with a production fluid including a bacteria, the bacteria present in the production fluid in a concentration of at least about 20/mL.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
A method of treating a sorbent having a species sorbed thereto includes reacting a first reactant and a second reactant to generate heat, and heating the sorbent with the generated heat to desorb the sorbed species form the sorbent. The first reactant includes a molecule having the same chemical identity as the sorbed species. Systems for carrying out such methods are provided.
B01D 53/02 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography
B01J 20/22 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising organic material
C10L 3/10 - Working-up natural gas or synthetic natural gas
Methods and systems for hybrid frac completion are disclosed. The methods include installing a hybrid completion system in a well and, in each zone of a first plurality of zones for plug & perf completion: activating an outer shroud of expanding shape memory polymer (SMP) around a liner, and perforating, using a perforation gun, a borehole wall. The methods further include, in each zone of the second plurality of zones for sliding sleeve completion: activating an SMP packer, and activating a sliding sleeve to expose the borehole wall. The methods further include fracturing the borehole wall by pressurizing the well; sealing, between each zone in the first and second plurality of zones, by actuating a plurality of isolation valves disposed in each zone of the first plurality of zones and each zone of the second plurality of zones; and removing the plurality of isolation valves to produce the well.
Methods and systems for hybrid frac completion are disclosed. The methods include installing a hybrid completion system in a well and, in each zone of a first plurality of zones for plug & perf completion: activating an outer shroud of expanding shape memory polymer (SMP) (208) around a liner (206), and perforating, using a perforation gun, a borehole wall. The methods further include, in each zone of the second plurality of zones for sliding sleeve completion: activating an SMP packer (204), and activating a sliding sleeve (200) to expose the borehole wall. The methods further include fracturing the borehole wall by pressurizing the well; sealing, between each zone in the first and second plurality of zones, by actuating a plurality of isolation valves (202) disposed in each zone of the first plurality of zones and each zone of the second plurality of zones; and removing the plurality of isolation valves (202) to produce the well.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A eutectic composite may be utilized in oil and gas servicing. For example, a method of making such a composite may include: crosslinking a mixture including a polymer, a metaphosphate salt, and a plurality of eutectic alloy particles to yield a eutectic composite; and producing a plurality of eutectic composite particles from the eutectic composite. Furthermore, an example composition may include: a cement; water; and a plurality of eutectic composite particles including eutectic alloy particles dispersed in a polymer crosslinked with a metaphosphate salt.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
32.
ASSEMBLY POINT SYSTEM WITH ACTIVE AIR QUALITY AND INDUSTRIAL GAS EMISSIONS MONITORING
A facility safety method includes establishing, at distinct locations relative to the facility, one or more smart assembly point systems (SAPS), detecting at each SAPS environmental parameters including wind speed, wind direction, ambient temperate and gas of interest presence, determining if a hazardous condition exists based on the detected parameters, alerting personnel of the hazardous condition, said alerting including providing the location of a SAPS at a clean air assembly point, and conducting a personnel headcount at the SAPS at the clean air assembly point. In certain embodiments, a SAPS structure having four backlit sides with transparent lettering that are photocell-activated at night time or conditions of low visibility is used.
G08B 7/06 - Signalling systems according to more than one of groups Personal calling systems according to more than one of groups using electric transmission
G08B 21/12 - Alarms for ensuring the safety of persons responsive to undesired emission of substances, e.g. pollution alarms
A system and method are described for making a proppant. The system includes a plurality of pumps for a first solution with an emulsion stabilizer, a matrix polymer, and a monomer; a second solution with an initiator, and a plant-based filler. The system includes a microfluidic device with a plurality of channels that receive the solutions, at least one channel junction where the solutions mix to form an emulsion, and a collecting zone. The process includes dissolving a matrix polymer, an emulsion stabilizer, and a monomer in a solvent to form a first solution and dissolving an initiator in another solvent to form a second solution, then adding a plant-based filler to the first or second solution, then feeding the solutions to a microfluidic device to form an emulsion, polymerizing the emulsion to form a proppant, and collecting the proppant.
A sonde adapted for determining one or more parameters related to hydrogen at a subsurface location. The sonde includes: a plurality of centralizer arms forming an interior space having a proximal portion and a distal portion; and a plurality of fiber optic Raman probes each disposed at the proximal portion or the distal portion of the interior space and proximate a respective one of the plurality of centralizer arms, the plurality of fiber optic Raman probes being adapted to measure a hydrogen concentration in a downhole measurement. The sonde also includes a plurality of optical probes each disposed at another of the distal portion or the proximal portion of the interior space and proximate a same or different one of the plurality of centralizer arms, the plurality of optical probes being adapted to measure downhole local gas holdup.
A method of using a reinforcement learning algorithm to plan a horizontal well characterized by a starting point (heel (TE)) and an end point (toe (TD)) under a surface location comprises defining an environment for the well that takes into account depth constraints, hazard areas and the existence of pre-existing wells, executing a reinforcement learning algorithm that i) uses initial target TE and TD locations, ii) makes a determination whether a well can be planned in the environment using (TEdesired, TDdesired) and if it cannot, iii) executes actions to change the target locations to new locations, and determines a state and a reward for the new locations. One of the new locations obtains a higher reward as is-a favored location. It is then determined whether a well can be planned at the favored location based on the environment, and, if so, TE, TD and control points of the favored location are returned.
Described is a method for mitigating tar in a reservoir. Tar-mitigating bacteria is introduced downhole to a reservoir with tar. The tar-mitigating bacteria are delivered to a tar food source in the reservoir, triggering bacterial growth upon reaching the tar food source. The tar breaks apart, allowing the tar-mitigating bacteria to produce and release biosurfactants, thereby trapping the tar from the reservoir with the biosurfactants. The tar trapped by the biosurfactants is mobilized away from porous rock, and the trapped tar is removed from the reservoir.
C09K 8/582 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of bacteria
Systems and devices include a hydraulic cylinder piston including a piston rod having a first end and a second end opposite the first end; a piston head coupled to the first end of the piston rod; and two inflatable seals disposed around an outer circumference of the piston head, each inflatable seal including one or more chambers configured to receive hydraulic fluid to inflate the seal.
F15B 15/14 - Fluid-actuated devices for displacing a member from one position to anotherGearing associated therewith characterised by the construction of the motor unit of the straight-cylinder type
F16J 15/46 - Sealings with packing ring expanded or pressed into place by fluid pressure, e.g. inflatable packings
38.
METHODS FOR ACIDIZING SUBSURFACE FORMATIONS UTILIZING CORROSION INHIBITOR COMPOUNDS
A subsurface formation may be acidized by a method that may comprise injecting an acidic treatment fluid into an subsurface formation through a tubing of an extraction well, thereby exposing at least a portion of the tubing to an acidic environment. At least a portion of the tubing may be contacted by a corrosion inhibitor compound that may have the general structure as described herein.
The process of the present invention involves subjecting a hydrocarbon composition A to a liquid-liquid extraction step in an extraction vessel, in which an aprotic or a protic solvent is used as extraction medium. The application of such process allows for the purification of hydrocarbon compositions, in particular regarding the content of chlorine-containing compounds. Such chlorine content reduction is desirable for processing of the hydrocarbon composition in many different chemical processing operations, such as steam cracking operations. The presence of chlorine-containing compounds in higher contents may lead to corrosion of equipment in such processes, which may result in e.g. equipment failure and/or reduced time between service intervals of the equipment.
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 1/10 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal from rubber or rubber waste
C10G 53/06 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step including only extraction steps, e.g. deasphalting by solvent treatment followed by extraction of aromatics
40.
SYSTEM AND METHOD FOR DEPLOYING FIBER OPTIC CABLES WITH A CURED-IN-PLACE PIPE LINER
A system may include a wellbore (10) extending a first depth into a formation. Additionally, a cured-in-place pipe liner (100) may be coupled to walls (11) of the wellbore. One or more fiber optic cables (101, 102, 103) are embedded in the cured-in-place pipe liner (100) to monitor a curing of the cured-in-place pipe liner (100) and record well data. The one or more fiber optic cables (101, 102, 103) may be used to continuously monitor the wellbore (10) during a method for lining the wellbore is performed. The method for lining the wellbore (10) may include inserting the cured-in-place pipe liner (100) into the wellbore; forcing the cured-in-place pipe liner (100) against walls (11) of the wellbore; curing the cured-in-place pipe liner (100); monitoring the curing of the cured-in-place pipe liner (100) with the one or more fiber optic cables (101, 102, 103) embedded in the cured-in-place pipe liner (100); and coupling the cured-in-place pipe liner (100) to the walls (11) of the wellbore.
A system and a method for producing hydrogen are provided. An exemplary method for producing hydrogen. The method includes desulfurizing a natural gas stream to form a sweet gas stream, converting higher hydrocarbons in the sweet gas stream to methane to form a methane stream, converting a portion of the methane in the methane stream to a syngas stream in a membrane reformer, and separating a portion of hydrogen from the syngas stream as a permeate stream from the membrane reformer. The retentate stream from the membrane reformer is fed to an autothermal reformer to form an oxidized stream. The membrane reformer is heated with the oxidizer stream.
C01B 3/38 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using catalysts
C01B 3/50 - Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
In an implementation, a downhole robot for oil wells includes a pressure housing enclosing an internal gas-filled or vacuum-filled volume and at least one propulsion unit coupled to an end of the pressure housing. The downhole robot includes at least one centralization element. At least one sensor measures properties of interest with respect to the downhole robot and for an environment outside of the downhole robot. The downhole robot also includes a buoyancy system, an electrical power supply, an anchoring system, and a power system configured for non-contact operation.
In one implementation, a downhole robot includes a housing, electrically-powered equipment configured to perform operations of the downhole robot, a power source disposed inside the housing, the power source coupled by a current flow path to provide electrical current to power to the electrically-powered equipment, and a resettable latch disposed inside the housing. The resettable latch is configured to either interrupt flow of electrical along the current flow path or allow current to flow along the current flow path in response to a signal that wirelessly penetrates the housing.
An untethered downhole tool includes a housing and a propeller. The housing is configured to house a logging tool and a power supply. The housing defines a longitudinal axis. The propeller includes a propeller blade. The propeller is coupled to the power supply for receiving power from the power supply to rotate. The propeller is positioned at an end of the housing such that the axis of rotation of the propeller is substantially parallel and/or inline with the longitudinal axis of the housing for the untethered downhole tool to traverse a well.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Parsapur, Rajesh Kumar
Hodgkins, Robert Peter
Koseoglu, Omer Refa
Huang, Kuo-Wei
Rueping, Magnus
Sedjerari, Anissa Bendjeriou
Abstract
According to one or more embodiments, a zeolite beta material may be made by a method that may include adding a parent zeolite beta in a basic solution to form a basic zeolite beta suspension, adding water to the basic zeolite beta suspension to form a dilute basic zeolite beta suspension, hydrothermally treating the dilute basic zeolite beta suspension to form a hydrothermally treated mixture, and separating from the hydrothermally treated mixture a solid zeolite beta material consisting essentially of polymorph-A and polymorph-B. The molar ratio of polymorph-A to polymorph-B of the solid zeolite beta material is greater than molar ratio of polymorph-A to polymorph-B of the parent zeolite beta.
C01B 39/02 - Crystalline aluminosilicate zeolitesIsomorphous compounds thereofDirect preparation thereofPreparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactantsAfter-treatment thereof
B01J 29/70 - Crystalline aluminosilicate zeolitesIsomorphous compounds thereof of types characterised by their specific structure not provided for in groups
C01B 39/04 - Crystalline aluminosilicate zeolitesIsomorphous compounds thereofDirect preparation thereofPreparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactantsAfter-treatment thereof using at least one organic template directing agent, e.g. an ionic quaternary ammonium compound or an aminated compound
46.
METHOD AND SYSTEM FOR LOCATING AN UNTETHERED DOWNHOLE TOOL IN STEEL-CASED WELLBORES
A method for locating a downhole tool (100) in a wellbore (101) involves obtaining, by the downhole tool (100), a pressure measurement in the wellbore (101), generating a first depth estimate based on the pressure measurement, and anticipating a passing of the downhole tool (100) by a collar (122), based on the first depth estimate and a known depth of the collar (122). The method further involves, based on the anticipating of the passing of the downhole tool (100) by the collar (122), performing, by the downhole tool (100), a collar detection, and based on the collar detection resulting in a detection of the collar (122): generating an updated depth estimate, and reporting the updated depth estimate.
A method for measuring the purity of a glycol sample includes measuring the purity of the glycol sample via gas chromatography, measuring the purity of the glycol sample via evaporation, measuring the purity of the glycol sample via titration, and comparing the purity of the glycol sample from gas chromatography, evaporation, and titration to obtain an accurate purity. A system for measuring the purity of a glycol sample in a pipeline includes at least one type of testing equipment connected to the pipeline via at least one test line and an interfacial online data processor in communication with the at least one type of testing equipment. The at least one type of testing equipment includes a gas chromatography instrument, an evaporation instrument, and a titration instrument.
G01N 1/00 - SamplingPreparing specimens for investigation
G01N 25/14 - Investigating or analysing materials by the use of thermal means by using distillation, extraction, sublimation, condensation, freezing, or crystallisation
G01N 31/16 - Investigating or analysing non-biological materials by the use of the chemical methods specified in the subgroupsApparatus specially adapted for such methods using titration
G01N 35/00 - Automatic analysis not limited to methods or materials provided for in any single one of groups Handling materials therefor
King Abdullah University of Science and Technology (Saudi Arabia)
Inventor
Parsapur, Rajesh Kumar
Hodgkins, Robert Peter
Koseoglu, Omer Refa
Huang, Kuo-Wei
Rueping, Magnus
Sedjerari, Anissa Bendjeriou
Abstract
According to one or more embodiments, a zeolite beta material may be made by a method that may include adding a parent zeolite beta in a basic solution to form a basic zeolite beta suspension, adding water to the basic zeolite beta suspension to form a dilute basic zeolite beta suspension, hydrothermally treating the dilute basic zeolite beta suspension to form a hydrothermally treated mixture, and separating from the hydrothermally treated mixture a solid zeolite beta material consisting essentially of polymorph-A and polymorph-B. The molar ratio of polymorph-A to polymorph-B of the solid zeolite beta material may be greater than molar ratio of polymorph-A to polymorph-B of the parent zeolite beta.
B01J 29/70 - Crystalline aluminosilicate zeolitesIsomorphous compounds thereof of types characterised by their specific structure not provided for in groups
Method for identifying and developing a gas advanced horizontal well. The method includes obtaining a subsurface model for a subterranean region of interest encompassing a Khuff formation. The method further includes identifying the gas advanced horizontal well by determining a well location that meets a reservoir criterion based on the subsurface model and determining a planned wellbore path that meets a horizontal well directional plan criterion based on the subsurface model and an initial completions assessment. The method further includes determining a set of petrophysical logging tools based on the subsurface model and planned wellbore path, drilling the gas advanced horizontal well according to the planned wellbore path, and obtaining a petrophysical log across a reservoir section using the set of petrophysical logging tools. The method further includes completing the gas advanced horizontal well based on a position of the gas advanced horizontal well relative to the Khuff formation.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 99/00 - Subject matter not provided for in other groups of this subclass
50.
MULTIFUNCTIONAL WASTE ADDITIVES FOR SUBTERRANEAN FORMATION TREATMENT FLUIDS, AND METHODS AND SYSTEMS RELATED THERETO
Treatment fluids, systems, and methods including preparing a multifunctional waste additive (MWA) comprising a cellulose extract derived by contacting a plurality of cigarette filter waste with a solvent; preparing a treatment fluid comprising: a base fluid; an acid; a corrosion intensifier; and the MWA; introducing the treatment fluid into a wellbore drilled through a subterranean formation, the treatment fluid; and allowing the MWA to interact with at least a portion of a metal surface during the introducing.
A system may include a wellbore extending a first depth into a formation. Additionally, a cured-in-place pipe liner may be coupled to walls of the wellbore. One or more fiber optic cables are embedded in the cured-in-place pipe liner to monitor a curing of the cured-in-place pipe liner and record well data. The one or more fiber optic cables may be used to continuously monitor the wellbore during a method for lining the wellbore is performed. The method for lining the wellbore may include inserting the cured-in-place pipe liner into the wellbore; forcing the cured-in-place pipe liner against walls of the wellbore; curing the cured-in-place pipe liner; monitoring the curing of the cured-in-place pipe liner with the one or more fiber optic cables embedded in the cured-in-place pipe liner; and coupling the cured-in-place pipe liner to the walls of the wellbore.
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
52.
INVERTED SHROUD FIELD ASSEMBLY FOR GAS ACCUMULATION PREVENTION ABOVE ESPS AND METHOD OF USE
A method includes providing an electrical submersible pump assembly with a pump, an intake, shroud base flanges, a protector, and a motor. The method includes coupling the shroud base flanges to an intake downhole end using fasteners and a set of protector top bolt holes. The method includes locating a closed end of an inverted shroud between the intake and the protector. The inverted shroud includes a shroud base on the closed end, and an opposite open end that is open toward the packer. The method includes coupling the inverted shroud to the shroud base flanges. The packer is located uphole of the opposite open end at a distance causing a mixing of a gas pocket with the well fluid to form a combined gas and liquid mixture and directing the combined gas and liquid mixture in a direction toward the intake.
A method to control a flow rate in a fluid flow network is disclosed. The method includes setting the outlet port of an upstream pressure regulator in a flow control device to have a first constant pressure that is below a minimum upstream pressure delivered from a upstream portion to the inlet port of the upstream pressure regulator, setting the outlet port of a downstream pressure regulator in the flow control device to have a second constant pressure to maintain a constant pressure differential across the downstream pressure regulator, and maintaining, based on the minimum upstream pressure to the flow control device exceeding the first constant pressure and further based on the constant pressure differential maintained across the downstream pressure regulator, the flow rate of the flow control device at a constant value.
Techniques for updating hydrocarbon parameters include identifying well data associated with wells formed in subterranean formations of a hydrocarbon reservoir; determining a data density value for each well; assigning each well into a pressure grouping based on a wellbore pressure similarity of the well relative to an initial pattern well; generating a two-dimensional (2D) model of the hydrocarbon reservoir; converting the 2D model into a three-dimensional (3D) model of the hydrocarbon reservoir; and updating a permeability or a porosity associated with a grid cell of the 3D model.
A facility safety method includes establishing, at distinct locations relative to the facility, one or more smart assembly point systems (SAPS), detecting at each SAPS environmental parameters including wind speed, wind direction, ambient temperate and gas of interest presence, determining if a hazardous condition exists based on the detected parameters, alerting personnel of the hazardous condition, said alerting including providing the location of a SAPS at a clean air assembly point, and conducting a personnel headcount at the SAPS at the clean air assembly point. In certain embodiments, a SAPS structure having four backlit sides with transparent lettering that are photocell-activated at night time or conditions of low visibility is used.
G01M 3/04 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point
G08B 19/00 - Alarms responsive to two or more different undesired or abnormal conditions, e.g. burglary and fire, abnormal temperature and abnormal rate of flow
56.
METHOD FOR DEEP WELL TESTING AND PERMEABILITY DETERMINATION IN DIFFERENT DIRECTIONS
Methods and systems are disclosed. The method may include installing a fluid detection sensor in a first lateral extension from a primary wellbore, establishing a fluid conduit from a well-head to a second lateral extension from the primary wellbore, pumping a marker fluid through the fluid conduit from the well-head to the second lateral extension and into the subterranean region of interest. The method further includes detecting, using the fluid detection sensor, the marker fluid in the first lateral extension, wherein the marker fluid in the first lateral extension has flowed from the second lateral extension through the subterranean region of interest and determining the fluid flow characteristic of the subterranean region of interest based, at least in part, on the detected marker fluid.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
57.
METHOD FOR EVALUATING ADVANCED CONFORMANCE CONTROL, SWEEP EFFICIENCY, DEEP DIVERSION, AND WATER SHUTOFF TREATMENTS
Described is a method for evaluating oil recovery. The method includes performing a pre-coreflood process, a coreflood process, and a post-coreflood process. The pre-coreflood process includes preparing heterogenous cores samples with different structural configurations. The coreflood process includes injecting a treatment into the core samples and obtaining nuclear magnetic resonance (NMR) measurements of the treated core samples. NMR measurements are compared to assess performance of the treatment. The post-coreflood process includes conducting an X-ray micro-computerized topography (CT) scan and a Saturate, Aromatic, Resin, and Asphaltene (SARA) analysis on the treated core samples.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
58.
Stimulating Hydrocarbon Production in a Subsurface Reservoir
Systems and methods for performing targeted stimulation of a well drilled in a subsurface formation include performing a dynamic well test in the well; logging the well to generate one or more diagnostic well logs prior to stimulating the subsurface formation; identifying one or more zones in the well for targeted stimulation based on the injection test and the one or more diagnostic well logs; and performing the targeted stimulation at the identified one or more zones.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
59.
METHOD AND SYSTEM FOR HEAVY-DUTY PUMP CARTRIDGE REMOVAL
A method of removing a pump cartridge from a centrifugal pump includes arranging a removal plate about the pump cartridge and abutting the removal plate against a casing of the centrifugal pump, inserting a plurality of threaded rods through a plurality of fastener apertures defined in the removal plate and into a plurality of threaded holes in the pump cartridge, advancing a plurality of threaded nuts onto each threaded rod, applying a specified torque to a first set of two or more threaded nuts simultaneously to provide a jacking force to the pump cartridge, applying the specified torque to one or more additional sets of two or more threaded nuts simultaneously to provide an additional jacking force to the pump cartridge, and removing the pump cartridge from the centrifugal pump, wherein the jacking forces translate the pump cartridge through and out of the casing of the centrifugal pump.
A method includes providing a distributed acoustic sensing (DAS) system and a fiber sample. The DAS system includes a chamber and a signal generator positioned proximate to and outside the chamber. The method further includes manipulating the fiber sample into a desired shape, filling the chamber with a freezable liquid, wherein the freezable liquid is provided at room temperature, and placing the fiber sample into the chamber. The method also includes recording a first set of room temperature baseline measurements, freezing the freezable liquid, and recording a first set of frozen baseline measurements. The method further includes performing strain-sensing measurements while the signal generator is active, and melting the freezable liquid.
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Wei, Wei
Lu, Peng
Luo, Pan
Luo, Jihong
Abstract
System and method for modeling a Carbon Dioxide (CO2) concentration and distribution map in a sedimentary basin including geological zones and a data analysis manager coupled to a well in each of geological zones. The data analysis manager is configured to perform a method including obtaining well data and CO2 measurement data related to the geological zones, calculating a depth-dependent CO2 concentration value for each of the geological zones to form a geochemical model based on the well data, and applying exponential functions to the geochemical model. The method further includes developing an empirical model based on regressing the geochemical model with the exponential functions for each of the geological zones and the CO2 measurement data, generating a 3D depth map based on the well data, and calculating a 3D CO2 concentration and distribution map based, at least in part, on the empirical model.
The present invention relates to a process for decontamination of petrochemical compositions, the process involving subjecting a hydrocarbon composition (A) comprising inorganic and/or polar contaminants, preferably wherein the inorganic and/or polar contaminants are chlorine-containing contaminants, to the steps of: (i) a water wash treatment, and (ii) an adsorption treatment. Such process allows for the purification of hydrocarbon compositions such as pyrolysis oil products obtained from processing of waste plastic compositions so that such hydrocarbon compositions may be suitable for processing in petrochemical and/or refinery operations.
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 1/10 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal from rubber or rubber waste
C10G 53/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
C10G 53/08 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one sorption step
63.
PROCESS FOR DECONTAMINATION OF PETROCHEMICAL COMPOSITIONS OBTAINED FROM CHEMICAL RECYCLING OF POLYMER MATERIALS.
The present invention relates to a process for decontamination of petrochemical compositions, the process involving the steps of: (i) subjecting a hydrocarbon composition (A) comprising inorganic and/or polar contaminants to a water wash treatment, preferably wherein the inorganic and/or polar contaminants are chlorine-containing contaminants, to obtain a washed product (B); and (ii) subjecting the product (B) obtained from step (i) to a nitrogen bubbling treatment, to obtain a product (C). Such process allows for the purification of hydrocarbon compositions such as pyrolysis oil products obtained from processing of waste plastic compositions so that such hydrocarbon compositions may be suitable for processing in petrochemical and/or refinery operations.
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 1/10 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal from rubber or rubber waste
C10G 53/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
64.
PROCESS FOR DECONTAMINATION OF PETROCHEMICAL COMPOSITIONS OBTAINED FROM CHEMICAL RECYCLING OF POLYMER MATERIALS.
The process of the present invention involves the steps of: (a) a stripping step in a stripping vessel (1); (b) a first liquid-liquid extraction step in a first extraction vessel (2), in which an aprotic solvent is used as extraction medium; and (c) a second liquid-liquid extraction step in a second extraction vessel (3), in which a protic solvent is used as extraction medium wherein steps (a)-(c) may be applied in any order. The application of such process allows for the purification of hydrocarbon compositions to such extent that the content of chlorine-containing compounds may be reduced to below 1 ppm by weight. Such low chlorine content is desirable for processing of the hydrocarbon composition in many different chemical processing operations, such as steam cracking operations. The presence of chlorine-containing compounds in higher contents may lead to corrosion of equipment in such processes, which may result in e.g. equipment failure and/or reduced time between service intervals of the equipment. In view of the significant impact on process economics thereof, it is clearly desirable to avoid the presence of chlorine-containing compounds to any extent.
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 1/10 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal from rubber or rubber waste
C10G 21/02 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents with two or more solvents, which are introduced or withdrawn separately
C10G 53/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
65.
PROCESS FOR DECONTAMINATION OF PETROCHEMICAL COMPOSITIONS OBTAINED FROM CHEMICAL RECYCLING OF POLYMER MATERIALS.
The process of the present invention involves the steps of: (a) a stripping step in a stripping vessel (1); and (b) a liquid-liquid extraction step in an extraction vessel (2) wherein steps (a)-(b) may be applied in any order. The liquid-liquid extraction step (b) may be performed using a protic solvent as extraction medium, or using an aprotic solvent as extraction medium. The application of such process allows for the purification of hydrocarbon compositions, in particular regarding the content of chlorine-containing compounds. Such chlorine content reduction is desirable for processing of the hydrocarbon composition in many different chemical processing operations, such as steam cracking operations. The presence of chlorine-containing compounds in higher contents may lead to corrosion of equipment in such processes, which may result in e.g. equipment failure and/or reduced time between service intervals of the equipment. In view of the significant impact on process economics thereof, it is clearly desirable to recude the presence of chlorine-containing compounds to any extent.
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 1/10 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal from rubber or rubber waste
C10G 53/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
C10G 53/08 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one sorption step
C10G 53/16 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural parallel stages only
66.
CATALYST COMPOSITIONS THAT INCLUDE ZEOLITES WITH DIFFERENT SILICA TO ALUMINA MOLAR RATIOS
According to embodiments a catalyst composition may include from 10 wt.% to 50 wt.% of matrix material, from 10 wt.% to 30 wt.% of binder, and from 30 wt.% to 70 wt.% of a zeolite mixture. The zeolite mixture may comprise at least a first portion of zeolite and a second portion of zeolite. The first portion of zeolite may consist of zeolite having a silica to alumina molar ratio in a first range and the second portion of zeolite may consist of zeolite having a silica to alumina molar ratio in a second range. The silica to alumina molar ratio range of the first portion of zeolite and the silica to alumina molar ratio range of the second portion of zeolite do not overlap and may be separated by at least 5.
A system and a method for producing hydrogen are provided. An exemplary method includes desulphurizing a natural gas stream to form a sweet gas stream, converting higher hydrocarbons in the sweet gas stream to methane to form a methane stream, and converting a portion of the methane in the methane stream to a methane/syngas stream. A further portion of the methane in the methane/syngas stream is converted to form a syngas stream. The syngas stream is converted to a raw hydrogen stream and hydrogen is separated from the raw hydrogen stream.
C01B 3/38 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using catalysts
C01B 3/48 - 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 followed by reaction of water vapour with carbon monoxide
C01B 3/50 - Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
68.
FROZEN CHAMBER FOR DISTRIBUTED ACOUSTIC SENSING (DAS) CONFIGURATION TESTS AND DISPOSABLE DEPLOYMENT
A method includes providing a distributed acoustic sensing (DAS) system (100) and a fiber sample (106). The DAS system (100) includes a chamber (102) and a signal generator (110) positioned proximate to and outside the chamber (102). The method further includes manipulating the fiber sample (106) into a desired shape, filling the chamber with a freezable liquid (104), wherein the freezable liquid (104) is provided at room temperature, and placing the fiber sample (106) into the chamber (102). The method also includes recording a first set of room temperature baseline measurements, freezing the freezable liquid (104), and recording a first set of frozen baseline measurements. The method further includes performing strain-sensing measurements while the signal generator (110) is active, and melting the freezable liquid (104).
G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
G01N 29/07 - Analysing solids by measuring propagation velocity or propagation time of acoustic waves
G01N 29/14 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic wavesVisualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object using acoustic emission techniques
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
Untethered, downhole robots are described. In some cases, the downhole robots are configured to have a density within + or – 20% of wellbore fluid in which it will be operating. In some cases, the downhole robots a controller capable of discerning deviation of the wellbore from vertical and, in response, control a buoyancy system to change longitudinal distribution of the weight of the robot, wherein the magnitude of the change in the longitudinal distribution of the weight suffices to reorient the robot.
A wellhead attachment can be used to deploy an untethered downhole tool into a well. The wellhead attachment includes a housing, a relief valve, a mounting flange, and a gate valve. The housing is configured to house the untethered downhole tool. The relief valve is in fluid communication with the housing and located at a first end of the wellhead attachment. The mounting flange is located at a second end of the wellhead attachment. The mounting flange is configured to couple to a tree of the well. The gate valve is coupled to the housing and the mounting flange. The gate valve is positioned between the housing and the mounting flange. The housing is positioned between the relief valve and the gate valve.
A system performs inner string cement operations in a wellbore. The system includes a stab-in stinger connected to a distal end of a drill string and a stab-in float shoe connected to a distal end of a casing. The stab-in float shoe includes a first check valve and a plug type rupture disc. The first check valve includes instructions configured to prevent a reverse flow of cement mixture. The plug type rupture disc is house between the first check valve and an outlet of the stab-in float shoe. The plug type rupture disc includes instructions configured to rupture at a predetermined threshold pressure and, once ruptured, permits flow of cement mixture from the annulus into the stab-in float shoe. A related method includes: enabling a stab-in stinger to stab-into a stab-in float shoe, starting the cementing operation and rupturing the plug-pe rupture discs at predetermined pressure.
A method that includes disposing a packer and an ESP inside a production tubing bore. The ESP includes a pump, a discharge, a shroud, and a bypass sub coupled to the shroud. The shroud includes a closed end coupled to a base of the pump. The packer, coupled to an outer surface of the shroud, is located downstream of the bypass sub. The method includes circulating liquids from the pumping base through the discharge to a shroud open end downstream of the packer thereby sealing the packer between the outer surface and the production tubing bore. The method includes pumping, using the pump device, the liquids through the production tubing using the bypass sub and performing a production operation using the wellhead assembly to obtain an amount of gas production.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Downloadable computer software using artificial intelligence (AI) for natural language processing, generation, understanding and analysis; Downloadable computer software using artificial intelligence (AI) for machine learning based data processing software; Downloadable computer software using artificial intelligence (AI) for the production of speech and text; Downloadable chatbot software using artificial intelligence (AI) for simulating conversations and answering queries; Downloadable chatbot software using large language models (LLMs) for simulating conversations and answering queries; Downloadable intelligent personal assistant software for performing generative AI tasks Providing on-line non-downloadable software using artificial intelligence (AI) for natural language processing, generation, understanding and analysis; Providing on-line non-downloadable software using artificial intelligence (AI) for machine learning based data processing software; Providing on-line non-downloadable software using artificial intelligence (AI) for the production of speech and text; Providing temporary use of online non-downloadable chatbot software using artificial intelligence (AI) for simulating conversations and answering queries; Providing temporary use of online non-downloadable chatbot software using large language models (LLMs) for simulating conversations and answering queries; Research in the field of artificial intelligence (AI) technology; Research in the field of computer natural language processing
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Downloadable computer software using artificial intelligence (AI) for natural language processing, generation, understanding and analysis; Downloadable computer software using artificial intelligence (AI) for machine learning based data processing software; Downloadable computer software using artificial intelligence (AI) for the production of speech and text; Downloadable chatbot software using artificial intelligence (AI) for simulating conversations and answering queries; Downloadable chatbot software using large language models (LLMs) for simulating conversations and answering queries; Downloadable intelligent personal assistant software for performing generative AI tasks Providing on-line non-downloadable software using artificial intelligence (AI) for natural language processing, generation, understanding and analysis; Providing on-line non-downloadable software using artificial intelligence (AI) for machine learning based data processing software; Providing on-line non-downloadable software using artificial intelligence (AI) for the production of speech and text; Providing temporary use of online non-downloadable chatbot software using artificial intelligence (AI) for simulating conversations and answering queries; Providing temporary use of online non-downloadable chatbot software using large language models (LLMs) for simulating conversations and answering queries; Research in the field of artificial intelligence (AI) technology; Research in the field of computer natural language processing
75.
METHODS FOR DISSOLVING TARGET CHEMICAL SPECIES INTO ABSORBENT LIQUIDS
A target chemical species, such as carbon dioxide, may be separated from a mixed gas by passing at least a portion of the mixed gas from a first chamber through a gas-selective membrane and into a second chamber, producing a concentrated gas. The concentrated gas has a higher concentration of the target chemical species than the mixed gas. At least a portion of the concentrated gas is passed through a diffusion-based membrane to a third chamber, where the third chamber includes an absorbent liquid in contact with one side of the diffusion-based membrane. The target chemical species is at least partially dissolved in the absorbent liquid and passed out of the system.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 53/22 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by diffusion
Methods for forming a treated water may comprise: obtaining a produced water comprising at least a divalent metal ion from a subterranean formation; introducing an accelerator into the produced water; wherein the accelerator comprises a zwitterionic compound; introducing a carbon dioxide gas into the produced water; allowing the carbon dioxide gas to react with the divalent metal ion in the presence of the accelerator to form a carbonate salt of the divalent metal ion; and removing the carbonate salt of the divalent metal ion from the produced water to form a treated water having a lower divalent metal ion concentration than the produced water.
Methods and systems are discussed. In some cases, the methods may include receiving a hydrocarbon-water contact. The hydrocarbon-water contact includes a base-polygon formed by projecting a location of contact points between a hydrocarbon zone and a water zone on an upper surface of a reservoir onto a horizontal plane. A wellbore planning system is used to determine a boundary zone that extends away from a boundary of the base-polygon, and to plan a wellbore trajectory penetrating the boundary zone.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
G01V 99/00 - Subject matter not provided for in other groups of this subclass
A flowmeter includes an inlet for receiving a wellbore fluid therein, an outlet for discharging the wellbore fluid and a stationary outer pipe extending between the inlet and the outlet and exhibiting a first diameter for receiving the wellbore fluid in an unrestricted state. One or more movable walls are coupled within the outer pipe and circumscribe a conical flow path defining an orifice at a downstream end thereof for constricting the wellbore fluid to a restricted state. The movable walls responsive to increasing mass flow rates of the wellbore fluid to expand the orifice and responsive to decreasing mass flow rates of the wellbore fluid to diminish the orifice. At least one sensor is operable to detect a parameter indicative of the pressures of the wellbore fluid in the unrestricted and restricted states.
Natural gas processing plants that are capable of handling sour gas can be adapted to handle large amounts of sweet gas by maintaining a low CO2/H2S ratio in the natural gas. Solvent mediated acid gas removal and a CO2 permeable membrane are used to yield a concentrated, high pressure H2S stream. The H2S stream is added to the natural gas.
C10L 3/10 - Working-up natural gas or synthetic natural gas
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 53/22 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by diffusion
80.
SYSTEM AND METHOD FOR RETRIEVING ALARM DATA FROM AN ISOLATED NETWORK
System and methods are disclosed herein for retrieving alarm data from an isolated network without compromising its security integrity. In an example, a data diode can be used to couple a first network and a second network. An alarm transmitter can be coupled to the first network, and an alarm receiver can be coupled to the second network. The alarm transmitter that can be operable to receive alarm data and communicate the alarm data by the data diode to the alarm receiver. The alarm receiver can be operable to output an alert based on the analysis of the alarm data.
A method for automatically counting and identifying articles in a received consignment as well as, among other things, determining if the articles are damaged. The method includes obtaining an article identifier of a received consignment containing one or more articles and acquiring one or more images of the consignment with a device with a camera. The method further includes determining, with a first machine-learned model processing the one or more images, a class of each of the one or more articles forming a set of determined classes and determining a quantity for each class in the set of determined classes. The method further includes making a first determination of whether the article identifier matches the set of determined classes and the quantity of each class in the set of determined classes, and determining, with a second machine-learned model, whether a first article of the one or more articles is damaged.
G06Q 10/087 - Inventory or stock management, e.g. order filling, procurement or balancing against orders
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
According to some embodiments, a process for producing hydrogen may comprise operating an electrolysis cell with a source of electricity to produce an oxygen stream and a hydrogen stream from water, reacting a hydrocarbon feedstock with the oxygen stream to partially oxidize the hydrocarbon feedstock, thereby producing a synthesis gas comprising hydrogen and carbon monoxide; passing the synthesis gas and a water stream to a heat exchanger to produce steam and to cool the synthesis gas; and reacting at least a portion of the synthesis gas from the heat exchanger and at least a portion of the steam from the heat exchanger. The source of electricity to the electrolysis cell for the totality of the operation of the electrolysis cell is not produced from energy provided by the combustion of hydrocarbons;
C01B 3/36 - 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 oxygen or mixtures containing oxygen as gasifying agents
C01B 3/16 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of inorganic compounds containing electro-positively bound hydrogen, e.g. water, acids, bases, ammonia, with inorganic reducing agents by reaction of water vapour with carbon monoxide using catalysts
C25B 1/04 - Hydrogen or oxygen by electrolysis of water
C25B 15/08 - Supplying or removing reactants or electrolytesRegeneration of electrolytes
83.
MEMBRANE ASSISTED REFORMING PROCESS FOR THE PRODUCTION OF LOW CARBON HYDROGEN
A system and a method for producing hydrogen are provided. An exemplary method includes desulphurizing a natural gas stream to form a sweet gas stream, converting higher hydrocarbons in the sweet gas stream to methane to form a methane stream, and converting a portion of the methane in the methane stream to a methane/syngas stream. A further portion of the methane in the methane/syngas stream is converted to form a syngas stream. The syngas stream is converted to a raw hydrogen stream and hydrogen is separated from the raw hydrogen stream.
C01B 3/38 - Production of hydrogen or of gaseous mixtures containing hydrogen by reaction of gaseous or liquid organic compounds with gasifying agents, e.g. water, carbon dioxide, air by reaction of hydrocarbons with gasifying agents using catalysts
C01B 3/50 - Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
C10G 45/04 - 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 hydrocarbonsHydrofinishing characterised by the catalyst used
In an implementation, a downhole robot for oil wells includes a pressure housing enclosing an internal gas-filled or vacuum-filled volume and at least one propulsion unit coupled to an end of the pressure housing. The downhole robot includes at least one centralization element. At least one sensor measures properties of interest with respect to the downhole robot and for an environment outside of the downhole robot. The downhole robot also includes a buoyancy system, an electrical power supply, an anchoring system, and a power system configured for non-contact operation.
B63G 8/22 - Adjustment of buoyancy by water ballastingEmptying equipment for ballast tanks
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
E21B 47/08 - Measuring diameters or related dimensions at the borehole
Untethered, downhole robots are described. In some cases, the downhole robots are configured to have a density within + or −20% of wellbore fluid in which it will be operating. In some cases, the downhole robots a controller capable of discerning deviation of the wellbore from vertical and, in response, control a buoyancy system to change longitudinal distribution of the weight of the robot, wherein the magnitude of the change in the longitudinal distribution of the weight suffices to reorient the robot.
A wellhead attachment can be used to deploy an untethered downhole tool into a well. The wellhead attachment includes a housing, a relief valve, a mounting flange, and a gate valve. The housing is configured to house the untethered downhole tool. The relief valve is in fluid communication with the housing and located at a first end of the wellhead attachment. The mounting flange is located at a second end of the wellhead attachment. The mounting flange is configured to couple to a tree of the well. The gate valve is coupled to the housing and the mounting flange. The gate valve is positioned between the housing and the mounting flange. The housing is positioned between the relief valve and the gate valve.
An untethered downhole tool includes a housing and a propeller. The housing is configured to house a logging tool and a power supply. The housing defines a longitudinal axis. The propeller includes a propeller blade. The propeller is coupled to the power supply for receiving power from the power supply to rotate. The propeller is positioned at an end of the housing such that the axis of rotation of the propeller is substantially parallel and/or inline with the longitudinal axis of the housing for the untethered downhole tool to traverse a well.
A target chemical species, such as carbon dioxide, may be separated from a mixed gas by passing at least a portion of the mixed gas from a first chamber through a gas-selective membrane and into a second chamber, producing a concentrated gas. The concentrated gas has a higher concentration of the target chemical species than the mixed gas. At least a portion of the concentrated gas is passed through a diffusion-based membrane to a third chamber, where the third chamber includes an absorbent liquid in contact with one side of the diffusion-based membrane. The target chemical species is at least partially dissolved in the absorbent liquid and passed out of the system.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 53/22 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by diffusion
89.
PROCESS FOR CONTROLLING CO2 OVER H2S RATIO IN OIL AND GAS PROCESSING INSTALLATIONS
Processes for determining formation salinity and/or processes for identifying oil bearing and/or water bearing zones in freshwater or relatively low salinity formations. In some embodiments, the process for determining formation water salinity can include measuring resistivity of a formation fluid sample at a first temperature (T1) and at a second temperature (T2), where T1 and T2 can be separated by a temperature difference (ΔT). The process can also include calculating a resistivity factor value based on the resistivities measured at T1 and T2. The process can also include determining a salinity of the formation fluid sample based on the resistivity factor value and the ΔT. The process can also include initiating a downhole operation using the determined salinity of the formation fluid sample.
G01N 27/06 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of a liquid
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 1/44 - Sample treatment involving radiation, e.g. heat
Processes for characterizing reservoir formation parameters such as water salinity and water saturation. In some embodiments, the process can include directing a heat impulse into a formation sample that can include a matrix component and a fluid component at an input location. The heat impulse can be allowed to pass through the formation sample such that a matrix impulse forms through the matrix component and a fluid impulse forms through the fluid component. The matrix and fluid impulses can convolve at a measurement location to provide a convolved impulse. A derivative analysis of the convolved impulse can be performed to derive thermal transient measurements. A fluid thermal model can be developed using the thermal transient measurements. The fluid thermal model can be integrated with one or more downhole logs and/or input parameters to create an integrated model. One or more reservoir parameters can be determined from the integrated model.
A system and a method for implementing a squeeze treatment to apply a scale inhibitor in a wellbore are provided. An exemplary method includes mixing a scale inhibitor pill. The scale inhibitor pill includes polyamino polyether methylene phosphonic acid (PAPEMP) and amino trimethylene phosphonic acid (ATMP). Pre-flush chemicals are injected into the wellbore. The scale inhibitor pill is injected into the wellbore. An over flush is injected into the wellbore. The wellbore is shut in for a target period of time and normal production is resumed.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
The present disclosure relates to cement compositions including Portland cement and volcanic ash. An exemplary cement composition includes about 10 wt % to about 85 wt % of Portland cement, and about 10% by weight of cement (BWOC) to about 70% BWOC of volcanic ash.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 40/00 - Processes, in general, for influencing or modifying the properties of mortars, concrete or artificial stone compositions, e.g. their setting or hardening ability
C04B 103/00 - Function or property of the active ingredients
A hydrocracking catalyst comprises an active cracking support. The active cracking support comprises a post-modified zeolite framework having zirconium atoms and titanium atoms substituting for aluminum atoms; wherein: a portion of the zirconium atom are substituted in the post-modified zeolite via 4-coordination; a portion of the zirconium atom are grafted to the post-modified zeolite via 5-coordination; and the titanium atoms are substituted in the post-modified zeolite framework via 4-coordination.
B01J 29/08 - Crystalline aluminosilicate zeolitesIsomorphous compounds thereof of the faujasite type, e.g. type X or Y
B01J 35/10 - Solids characterised by their surface properties or porosity
C01B 39/02 - Crystalline aluminosilicate zeolitesIsomorphous compounds thereofDirect preparation thereofPreparation thereof starting from a reaction mixture containing a crystalline zeolite of another type, or from preformed reactantsAfter-treatment thereof
C01B 39/06 - Preparation of isomorphous zeolites characterised by measures to replace the aluminium or silicon atoms in the lattice framework by atoms of other elements
C10G 47/20 - Crystalline alumino-silicate carriers the catalyst containing other metals or compounds thereof
A method for making zeolite-Y particles may include forming an initial zeolite precursor solution including an alumina source material and a silica source material in a solvent, and subjecting the initial zeolite precursor solution to a first heating process to form zeolite-Y particles in a residual liquid solution, and separating the zeolite-Y particles from the residual liquid solution. The residual liquid solution may include some remaining non-crystalized silica source material, and the residual liquid solution may have a different alumina to silica molar ratio than the initial zeolite precursor. The method may further include forming a recycled zeolite precursor solution that may include at least a portion of the residual liquid solution and one or both of additional alumina source material or additional silica source material, such that the recycled zeolite precursor solution has an alumina to silica molar ratio within 10% of the alumina to silica ratio of the initial zeolite precursor solution. The method may further include subjecting the recycled zeolite precursor solution to a second heating process to form additional zeolite-Y particles.
Techniques for determining properties of a rock sample include performing a plurality of series of permeability measurements of a rock sample with a permeability test assembly to derive permeability values, where each series includes permeability measurements of the rock sample at a respective, constant differential pressure between a particular confining pressure and a particular pore pressure; for each series of the plurality of series, performing a curve fit operation to determine a slope and an intercept of a curve associated with a selected Biot coefficient, the permeability values, and the particular pore pressures to generate a plurality of slope values and a plurality of intercept values; determining an effective stress coefficient of the rock sample; and determining an actual Biot coefficient of the rock sample.
A method of assessing a caprock for caprock defects comprises drilling a first well into a geologic sequence, the geologic sequence comprising a first subsurface formation, the caprock positioned above the first subsurface formation, and a second subsurface formation positioned above the caprock; sampling subsurface fluids of the geologic sequence for helium concentration within the second subsurface formation, within the caprock, and within the first subsurface formation; drilling a second well into the geologic sequence a pre-determined distance away from the first well; sampling the subsurface fluids for the helium concentration within the second subsurface formation, within the caprock, and within the first subsurface formation through the second well; determining whether a deviation exists between the helium concentration at the first well and at the second well, the deviation indicating the caprock defect is present; and halting further drilling into the geologic sequence upon determining the caprock defect is present.
A method for sequestering CO2 in a subterranean formation and a method for sequestering CO2 in a subterranean formation during an enhanced oil recovery treatment include preparing a solution comprising CO2 and from 0.01% by weight (wt. %) to 10 wt. % of a CO2 soluble alkoxylate surfactant based on the total weight of CO2, processing the solution through a dispersing unit in fluid communication with an injection well, and injecting the dispersion into the injection well of the formation, thereby sequestering CO2 in the formation. The method for sequestering CO2 in a subterranean formation during an enhanced oil recovery treatment includes introducing an enhanced oil recovery treatment to the formation. A system for sequestering CO2 in a formation includes an injection well in fluid communication with a formation, an injection unit, and a dispersing unit that is in fluid communication with the injection unit and the injection well.
E21B 41/00 - Equipment or details not covered by groups
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
C09K 8/594 - Compositions used in combination with injected gas
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
A swing check valve includes a valve body that defines a fluid flow path from a fluid inlet to a fluid outlet; a flapper coupled to the valve body and moveable between a first position to allow fluid flow in a primary flow direction through the fluid flow path and a second position to impede fluid flow in a secondary flow direction through the fluid flow path; a seat coupled to or integral with the valve body within the fluid flow path such that the flapper is apart from a face of the seat in the first position and abuts the face of the seat in the second position, the seat including a groove formed in the face; and a dampening ring positioned within the groove and including an interface aligned with the face of the seat such that the flapper abuts the interface in the second position.
A treatment fluid including an aqueous colloid containing a first surfactant and a plurality of nanoparticles encapsulated by a second surfactant. A method for preparing a treatment fluid including mixing a plurality of metallic oxide nanoparticles with a first surfactant to form an intermediate solution. A second surfactant is added to the intermediate solution to form nanoparticles encapsulated by the second surfactant. A method of extracting hydrocarbons from a well environment and storing carbon dioxide in the well environment including injecting a first amount of carbon dioxide and a first amount of a treatment fluid into a hydrocarbon reservoir via an injection well in a well environment. The treatment fluid treatment fluid including an aqueous colloid containing a first surfactant and a plurality of nanoparticles encapsulated by a second surfactant. Subsequently, determining a byproduct amount of the carbon dioxide extracted from the well environment.
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
