This disclosure relates to methods of determining the sulfur-content in a gas sample or liquefied petroleum gas sample comprising sulfur-containing compounds, including derivatizing the sulfur-containing compounds and analyzing the derivatized sulfur-containing compounds.
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (China)
Inventor
Zhang, Houzhu
Liang, Hong
Chen, Jinhong
Liu, Lu
Abstract
Examples of methods and systems are disclosed. The methods may include obtaining seismic data regarding a subsurface region of interest, wherein the seismic data includes a plurality of time-space waveforms. The methods may also include obtaining a seismic velocity model regarding the subsurface region of interest and determining a seismic image based, at least in part, on the plurality of time-space waveforms and the seismic velocity model. The methods may further include generating a filtered seismic image by applying a geometric flow filter to the seismic image, wherein applying the geometric flow filter comprises simulating a geometric flow using a tension spline function. The methods may still further include determining a geological boundary based, at least in part, on the filtered seismic image. The method may also include determining a drilling target in the subsurface region based, at least in part, on the geological boundary.
A method of determining an API gravity of a crude oil includes obtaining a reservoir sample containing the crude oil, separating an aromatic fraction from the reservoir sample, analyzing the aromatic fraction using a gas chromatography mass spectrometry (GC-MS) instrument, determining peak areas and a ratio of 4-methyldibenzothiophene and 1-methyldibenzothiophene, and determining the API gravity of the crude oil in the reservoir sample using an empirical correlation between API gravity and the ratio of 4-methyldibenzothiophene to 1-methyldibenzothiophene. A method of determining productivity of a region of a reservoir includes determining an API gravity of a crude oil in the sample from the region of the reservoir using an empirical correlation between API gravity and the ratio of 4-methyldibenzothiophene to 1-methyldibenzothiophene, and based on the API gravity of the sample, determining the productivity of the region of the reservoir.
PROCESS OF CONVERTING HYDROGEN SULFIDE AND CARBON DIOXIDE TO METHANE AND SOLID SULFUR ON CARBON-BASED CATALYSTS UNDER MILDER CONDITIONS WITH REDUCED CARBON FOOTPRINT
Systems and methods for producing methane and sulfur. A first system includes a condensate separation system to separate a feed stream of mixed hydrocarbons, an acid gas removal system to produce a methane product stream and a reactant gas stream of carbon dioxide and hydrogen sulfide and a catalytic reactor configured to react the carbon dioxide and the hydrogen sulfide from the reactant gas stream using a carbon-based catalyst and produce an effluent methane stream, an effluent sulfur stream, and a waste stream. Another system for producing methane and sulfur includes a first separation system to separate water vapor and oxygen to produce a hydrogen sulfide stream, a catalytic reactor configured to react a separated carbon dioxide stream and the hydrogen sulfide stream using a carbon-based catalyst and produce a methane stream and a sulfur stream.
A fluid sensor device for measuring properties of a fluid is disclosed. The fluid sensor device includes a leaf cell sensor having a piezoelectric structure acting on a subdomain of the fluid that flows through the piezoelectric structure to create an intrinsic Helmholtz cavity response, and an enclosure enclosing the leaf cell sensor and including (i) a flowthrough shroud having an inlet that allows the fluid to enter the enclosure and pass across the leaf cell sensor, and a Helmholtz cavity wall that couples the intrinsic Helmholtz cavity response with an external acoustic field of the leaf sensor to increase a measurement sensitivity, (ii) a cylindrical housing having an outlet that allows the fluid to exit the enclosure, and (iii) a pressure feedthrough connector that transmits an electrical signal induced by the intrinsic Helmholtz cavity response to represent the properties of the fluid.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 9/36 - Analysing materials by measuring the density or specific gravity, e.g. determining quantity of moisture
G01N 29/024 - Analysing fluids by measuring propagation velocity or propagation time of acoustic waves
G01N 29/22 - 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 Details
Described is a method for assessing quality of an amine-based shale inhibitor in drilling fluid. A relationship between a concentration of the amine-based shale inhibitor in a drilling fluid and turbidity is established (200) by preparing drilling fluid solutions with varying concentrations of the amine-based shale inhibitor (600), allowing the drilling fluid solutions to form precipitates (602), and analyzing turbidity of the drilling fluid solutions (604). A sample of a drilling fluid with an unknown concentration of amine- based shale inhibitor is obtained (606). Using the established relationship, a concentration of the amine-based shale inhibitor in the sample of the drilling fluid is estimated (608).
22, such as in above saline aquifers (104). The testing system for performing the method (600) includes a core container (420) in fluid communication with an upstream reservoir (430) and an upstream pump (432), further in fluid communication with a downstream liquid reservoir (440) and a downstream liquid pump (442), and further in fluid communication with a downstream gas reservoir (441) and a downstream gas pump (462). The method (600) includes determining transient hydraulic conductivity and hydraulic gradient of a caprock core sample (411) using the testing system based on non-Darcy flow.
Methods and systems for selectively altering permeability of a subterranean formation rock surface. The methods and systems include introducing a treatment fluid into a target zone in a wellbore drilled through a subterranean formation comprising a plurality of surface flow modifiers (SFMs). The SFMs are selected from the group consisting of a superhydrophobic chemical, a superomniphobic chemical, an ionic liquid chemical, and any combination thereof. The SFMs bind to the rock surface of the subterranean formation within the wellbore at the target zone to at least partially obstruct a rock pore thereof and alter permeation of the rock surface to favor hydrocarbon permeation over water permeation.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
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 (202) and a field scale set of models (204). The reservoir is modeled using the lab scale set of models (202) by scanning a sample of the reservoir into the lab scale set of models (202) 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 (204) 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.
Methods, devices, and systems are discussed. In some cases, the methods (500) may include conveying (520) a downhole tool into a wellbore. The downhole tool includes a release sub disposed between a first section of the downhole tool and a second section of the downhole tool. The release sub includes: a first portion including a threaded pin and an electric motor, and a second portion including a threaded box where the threaded pin is threaded into the threaded box to couple the first portion to the second portion. The methods may further include causing (530) the electric motor to rotate the threaded pin relative to the threaded box to decouple the first portion from the second portion, such that the first section of the downhole tool is at least partially detached from the second section of the downhole tool.
E21B 31/107 - Fishing for or freeing objects in boreholes or wells using impact means for releasing stuck parts, e.g. jars
11.
A PROCESS OF CONVERTING HYDROGEN SULFIDE AND CARBON DIOXIDE TO METHANE AND SOLID SULFUR ON CARBON-BASED CATALYSTS UNDER MILDER CONDITIONS WITH REDUCED CARBON FOOTPRINT
Systems and methods for producing methane and sulfur. A first system 100 includes a condensate separation system 106 to separate a feed stream 104 of mixed hydrocarbons, an acid gas removal system 111 to produce a methane product stream 114 and a reactant gas stream 112 of carbon dioxide and hydrogen sulfide and a catalytic reactor 120 configured to react the carbon dioxide and the hydrogen sulfide from the reactant gas stream 112 using a carbon -based catalyst and produce an effluent methane stream 122, an effluent sulfur stream 123, and a waste stream 127. Another system 200 for producing methane and sulfur includes a first separation system 204 to separate water vapor and oxygen to produce a hydrogen sulfide stream 210, a catalytic reactor 212 configured to react a separated carbon dioxide stream 208 and the hydrogen sulfide stream 210 using a carbon-based catalyst and produce a methane stream 214 and a sulfur stream 215.
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 boehmite, γ-aluminum oxide, corundum, and gibbsite.
C01F 7/441 - Dehydration of aluminium oxide or hydroxide, i.e. all conversions of one form into another involving a loss of water by calcination
B01J 20/08 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising oxides or hydroxides of metals not provided for in group comprising aluminium oxide or hydroxideSolid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising oxides or hydroxides of metals not provided for in group comprising bauxite
A fluid sensor device (52) for measuring properties of a fluid is disclosed. The fluid sensor device includes a leaf cell sensor having a piezoelectric structure acting on a subdomain of the fluid that flows through the piezoelectric structure to create an intrinsic Helmholtz cavity response, and an enclosure enclosing the leaf cell sensor and including (i) a flowthrough shroud (501) having an inlet that allows the fluid to enter the enclosure and pass across the leaf cell sensor, and a Helmholtz cavity wall (502) that couples the intrinsic Helmholtz cavity response with an external acoustic field of the leaf sensor to increase a measurement sensitivity, (ii) a cylindrical housing having an outlet that allows the fluid to exit the enclosure, and (iii) a pressure feedthrough connector (507) that transmits an electrical signal induced by the intrinsic Helmholtz cavity response to represent the properties of the fluid.
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 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).
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.
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 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
20.
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.
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 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
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 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
30.
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 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
32.
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
34.
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 method for locating a downhole tool in a wellbore involves obtaining, by the downhole tool, a pressure measurement in the wellbore, generating a first depth estimate based on the pressure measurement, and anticipating a passing of the downhole tool by a collar, based on the first depth estimate and a known depth of the collar. The method further involves, based on the anticipating of the passing of the downhole tool by the collar, performing, by the downhole tool, a collar detection, and based on the collar detection resulting in a detection of the collar: generating an updated depth estimate, and reporting the updated depth estimate.
E21B 47/092 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting magnetic anomalies
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
39.
PROCESS FOR CONTROLLING CO2 OVER H2S RATIO IN OIL AND GAS PROCESSING INSTALLATIONS
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.
Hydrogen may be produced from ammonia by catalytic reaction. For example, a method of hydrogen production may include: introducing ammonia to a reactor, wherein the reactor includes therein a catalyst, wherein the catalyst includes a high entropy alloy, and wherein the high entropy alloy has an entropy, S, such that S ≥ 11.31 J K-1mol-1; reacting the ammonia in the presence of the catalyst to form hydrogen gas and nitrogen gas; and separating the hydrogen gas from the nitrogen gas to produce a hydrogen stream including the hydrogen gas from the reactor.
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
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.
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 postmodified zeolite via 5-coordination; and the titanium atoms are substituted in the post-modified zeolite framework via 4-coordination.
B01J 29/89 - Silicates, aluminosilicates or borosilicates of titanium, zirconium or hafnium
B01J 37/02 - Impregnation, coating or precipitation
C10G 47/02 - Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, to obtain lower boiling fractions characterised by the catalyst used
45.
METHODS AND SYSTEMS FOR AUTOMATICALLY POSITIONING WELLS BASED UPON A RESERVOIR MODEL
Methods and systems are discussed. In some cases, the methods (700) may include receiving (702) 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 (704) a boundary zone that extends away from a boundary of the base-polygon, and to plan (706) a wellbore trajectory penetrating the boundary zone.
A printhead (100) for three-dimensional printing of concrete includes a main body (120) and a regulator device (140). The main body (120) includes a multi-stage, convergent-divergent cylinder (125a), shearing blades (126), a pressure chamber (128), and a secondary inlet (130). The pressure chamber (128) surrounds the cylinder for temporary storage and regulated processing of a secondary fluid. The secondary inlet (130) transfers the secondary fluid from the pressure chamber (128) to the multi-stage, convergent-divergent cylinder (125a) to form a mixture, which is discharged from the printhead (100). The printhead can, for example, be used for additive manufacturing of cement-based materials.
B28B 1/00 - Producing shaped articles from the material
B01F 23/232 - Mixing gases with liquids by introducing gases into liquid media, e.g. for producing aerated liquids using flow-mixing means for introducing the gases, e.g. baffles
B01F 23/237 - Mixing gases with liquids by introducing gases into liquid media, e.g. for producing aerated liquids characterised by the physical or chemical properties of gases or vapours introduced in the liquid media
B01F 25/314 - Injector mixers in conduits or tubes through which the main component flows wherein additional components are introduced at the circumference of the conduit
B01F 25/433 - Mixing tubes wherein the shape of the tube influences the mixing, e.g. mixing tubes with varying cross-section or provided with inwardly extending profiles
B28C 5/06 - Apparatus or methods for producing mixtures of cement with other substances, e.g. slurries, mortars, porous or fibrous compositions without using driven mechanical means effecting the mixing the mixing being effected by the action of a fluid
B28C 5/46 - Arrangements for applying super- or sub-atmospheric pressure during mixingArrangements for cooling or heating during mixing
C04B 40/02 - Selection of the hardening environment
E04G 21/04 - Devices for both conveying and distributing
47.
METHOD FOR MANAGING SANDING VOLUME EXPECTATION IN WEAK SANDSTONE BASED ON PLASTIC ZONE VOLUME
Described is a method for managing an expectation on sanding volume in weak sandstone. In situ data related to a region of sandstone proximate a well is acquired. Measured property data corresponding to samples from the region of sandstone are obtained, and a chemical consolidation treatment is performed on the samples. Chemical consolidation treatment data is then obtained. The measured property data and the chemical consolidation treatment data is supplied as inputs to a simulator. The simulator performs simulations with and without chemical consolidation treatment. Based on the simulations, a correlation between a well flow rate and an effect of the chemical consolidation treatment is determined.
G01N 3/08 - Investigating strength properties of solid materials by application of mechanical stress by applying steady tensile or compressive forces
C09K 8/575 - Compositions based on water or polar solvents containing organic compounds
E21B 33/138 - Plastering the borehole wallInjecting into the formation
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
A method to determine downhole fluid flow rate of a wellbore (120) is disclosed. The method includes generating, using sensors (135a, 135b) of a discharge sub (133a) and a suction sub (133b) coupled to an electrical submersible pump (ESP), monitoring data of the ESP (131) that is suspended in the wellbore (120) via a production tubing (120a) to facilitate well fluid (121a) flow to the Earth's surface through the production tubing (120a), wirelessly transmitting, using wireless transmitters (135a, 135b) of the discharge sub (133a) and the suction sub (133b), the monitoring data to a monitoring sub (133d) coupled to an electrical motor (13 le) of the ESP (131), transmitting, by the monitoring sub (133d) to a downhole flow rate analyzer at the Earth's surface, monitoring data wirelessly received from the discharge sub (133a) and the suction sub (133b), and determining, by the downhole flow rate analyzer, the downhole flow rate of the well fluid (121a) by analyzing the monitoring data.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Almajnouni, Khalid Ali
Cui, Mengmeng
Castano, Pedro
Sabate, Jorge Gascon
Abstract
Methods for distributing catalyst in a counter-current reactor may include passing the catalyst from a catalyst hopper to a perforated plate distributor; distributing the catalyst into a reaction zone of the counter-current reactor by passing the catalyst from a catalyst discharge zone, through the perforations of the perforated plate distributor, into the reaction zone, wherein the catalyst enters the perforations of the perforated plate distributor at a superficial velocity from 0.01 m/s to 10 m/s, and the superficial velocity is in a substantially downward direction; and passing a hydrocarbon feed stream into the reaction zone, wherein the catalyst moves in a substantially downward direction through the reaction zone, the hydrocarbon feed stream moves in a substantially upward direction through the reaction zone, and wherein contacting the catalyst with the hydrocarbon feed stream cracks one or more components of the hydrocarbon feed stream and forms a hydrocarbon product stream.
B01J 8/00 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes
B01J 8/12 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with moving particles moved by gravity in a downward flow
B01J 8/24 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with fluidised particles according to "fluidised-bed" technique
B01J 8/18 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with fluidised particles
B01J 8/26 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with fluidised particles according to "fluidised-bed" technique with two or more fluidised beds, e.g. reactor and regeneration installations
B01J 8/38 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with fluidised particles according to "fluidised-bed" technique with fluidised bed containing a rotatable device or being subject to rotation
50.
SPLIT DOWNHOLE TRANSFORMER FOR HIGH POWER APPLICATIONS
A system includes production tubing installed in the well and a female component (200) connected to the production tubing comprising a female component body located in a housing, primary coils (214) wound through the female component body, and a borehole delineated by an inner circumferential surface of the female component body and having a borehole axis. The borehole outlines a shape. The system also includes a male component (300) electrically connected to the electrically powered tool and configured to be inserted into the borehole of the female component (200). The male component (300) includes a male component body having an external surface formed in the shape, secondary coils (314) wound through the male component body, and a conduit extending through the male component body and having a conduit axis. The borehole axis and the conduit axis line up when the male component (300) is inserted into the borehole of the female component (200). The system further includes a split downhole transformer (400) formed by installation of the male component (300) into the female component (200). Formation of the split downhole transformer (400) allows power to transfer from a surface location to the electrically powered tool installed in the production tubing downhole in the well.
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Saudi Arabia)
Inventor
Spyropoulos, Emmanouil
Al Mehthel, Mohammed
Maslehuddin, Mohammed
Al Abduljabbar, Sami A.
Wohaibi, Saleh A.
Khaliluddin, Mohammed
Abstract
The disclosure relates to compositions that include sand mixed with a stabilizing agent that includes i) hydrocarbon derivative fibers and cement, ii) acrylic-based polymer emulsions, or iii) hydrocarbon derivative fibers and acrylic-based polymer emulsions, as well as related methods.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
A fluid conductivity sensor (FCS) system (100) for determining a water void fraction in a fluid mixture flows comprises a duct (130) containing the fluid mixture flows; a dielectric window system operatively connected to the duct (130), wherein the dielectric window system comprises a first dielectric window (142) built-into a first surface of a wall of the duct (130) and a second dielectric window (144) built-into a second surface of the wall aligned and opposite to the first surface; a split-toroidal loop-gap resonator (split- TLGR) system operatively connected to the dielectric window system and the duct (130), wherein the split- TLGR system comprises a first split- TLGR (112) built-into the first dielectric window (142) and a second split- TLGR (116) built-into the second dielectric window (144); and a vector network analyzer (VNA) operatively connected to the split-TLGR system and configured to measure the fluid conductivity, wherein the water void fraction is derived from the fluid conductivity.
G01F 1/704 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
G01F 1/712 - Measuring the time taken to traverse a fixed distance using auto-correlation or cross-correlation detection means
G01F 1/74 - Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
G01F 1/66 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
Systems include a device and a pipeline. The device (235) includes a body (230). The body (230) includes jetting elements and a sealing disc (300). The jetting elements include a hose (500, 505), an opening (200, 215), channels (205, 220), and nozzles (210, 225). The jetting elements are configured to direct pressurized fluid (510, 515) through the body (230) for purposes of cleaning and propelling the device (235) along the pipeline (105). The sealing discs (300) are configured to maintain a seal between the body (230) of the device (235) and the inside wall of the pipeline (105).
B08B 9/049 - Cleaning the internal surfacesRemoval of blockages using cleaning devices introduced into and moved along the pipes having self-contained propelling means for moving the cleaning devices along the pipes
F16L 55/36 - Constructional aspects of the propulsion means, e.g. towed by cables being self-contained jet driven
A sour gas stream is sub-stoichiometrically combusted to produce soot and a sour syngas stream. At least 10% of the carbon in the sour gas stream is converted into the soot. At least a portion of the hydrogen sulfide of the sour syngas stream is reacted with sulfur dioxide to produce a syngas stream comprising the carbon dioxide, the carbon monoxide, the hydrogen, water, elemental sulfur vapor, a residual portion of the hydrogen sulfide, and a residual portion of the sulfur dioxide. The syngas stream is reacted with steam to produce a shifted sour gas stream including more carbon dioxide, more hydrogen, more hydrogen sulfide, and less carbon monoxide in comparison to the syngas stream. Water and hydrogen sulfide is separated from the shifted sour gas stream to produce a sweet gas stream. The sweet gas stream is separated into a hydrogen product stream and an exhaust stream.
C10K 3/04 - Modifying the chemical composition of combustible gases containing carbon monoxide to produce an improved fuel, e.g. one of different calorific value, which may be free from carbon monoxide by catalytic treatment reducing the carbon monoxide content
C01B 17/04 - Preparation of sulfurPurification from gaseous sulfur compounds including gaseous sulfides
C10K 1/10 - Purifying combustible gases containing carbon monoxide by washing with liquidsReviving the used wash liquors with aqueous liquids
55.
COGENERATION OPTIMIZATION MODEL IN UPSTREAM CRUDE PROCESSING FACILITY
A method for developing a model to optimize operations for a cogen facility is provided. The method includes collecting data on the operation of the cogen facility and creating an objective function to minimize total operating cost of the cogen facility, wherein the objective function is based, at least in part, on a fuel cost and a net power cost. An output is provided from the objective function, wherein the output is used to control a mixture of gas turbines used in the cogen facility and steam generation rates.
System and method for a bottom hole assembly, BHA (104) in production tubing including an electrical submersible pump, ESP (124), multi-resettable packer assembly (126), sensor, power and communications bus, and control system. The multi-resettable packer assembly (126) includes a multi-resettable packer (202), a port sub (208) hydraulically connecting production tubing to the ESP (124), an inner mandrel (304) inside the multi - resettable packer (202) axially movable within the multi-resettable packer (202) and port sub (208), and a stroker tool (206) configured to compress and decompress the multi-resettable packer (202) to seal and unseal an inner surface of production tubing. The stroker tool (206) includes slips to grip the inner surface and a piston (308) that extends from and retracts into the stroker tool (206). The sensor is configured to measure operating data including a pressure measurement. The power and communications bus powers and transmits signals to the BHA (104). The control system monitors operating data and controls the stroker tool via the power and communications bus.
A method may use a core sampling system for collecting a core sample with a reference log of a first property. The method may use a wellbore logging system for recording uncalibrated well logs with a target log of the first property. The method may use a computer processor for obtaining an uncalibrated geological model, determining a bulk-shift depth correction based on a first cost function, forming a bulk-shifted log by applying the bulk-shift depth correction to the target log, identifying a plurality of log event pairs, determining, for each of the log event pairs, a local-shift depth correction based on a second cost function, forming a local-shift depth correction table from the local-shift depth correction for the log event pairs, and forming a calibrated geological model based, at least in part, on the uncalibrated geological model and the local-shift depth correction table.
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 5/06 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging for detecting naturally radioactive minerals
G06T 7/32 - Determination of transform parameters for the alignment of images, i.e. image registration using correlation-based methods
58.
FLUID CONDUCTIVITY SENSOR BASED ON MAGNETO-INDUCTIVE POWER TRANSFER DISSIPATION
A fluid conductivity sensor (FCS) system for determining a water void fraction in a fluid mixture flows comprises a duct containing the fluid mixture flows; a dielectric window system operatively connected to the duct, wherein the dielectric window system comprises a first dielectric window built-into a first surface of a wall of the duct and a second dielectric window built-into a second surface of the wall aligned and opposite to the first surface; a split-toroidal loop-gap resonator (split-TLGR) system operatively connected to the dielectric window system and the duct, wherein the split-TLGR system comprises a first split-TLGR built-into the first dielectric window and a second split-TLGR built-into the second dielectric window; and a vector network analyzer (VNA) operatively connected to the split-TLGR system and configured to measure the fluid conductivity, wherein the water void fraction is derived from the fluid conductivity.
G01F 1/712 - Measuring the time taken to traverse a fixed distance using auto-correlation or cross-correlation detection means
G01F 25/10 - Testing or calibration of apparatus for measuring volume, volume flow or liquid level or for metering by volume of flowmeters
G01P 5/22 - Measuring speed of fluids, e.g. of air streamMeasuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring the time taken by the fluid to traverse a fixed distance using auto-correlation or cross-correlation detection means
59.
MODIFIED ZEOLITES THAT INCLUDE AMINE FUNCTIONALITIES AND METHODS FOR MAKING SUCH
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Hodgkins, Robert Peter
Koseoglu, Omer Refa
Huang, Kuo-Wei
Rueping, Magnus
Sedjerari, Anissa Bendjeriou
Parsapur, Rajesh Kumar
Pandey, Swechchha
Abstract
Modified zeolite may include a microporous framework including a plurality of micropores having diameters of less than or equal to 2 nm, wherein the microporous framework includes at least silicon atoms and oxygen atoms; a plurality of mesopores having diameters of greater than 2 nm and less than or equal to 50 nm, wherein the plurality of mesopores are ordered with cubic symmetry. The modified zeolite also includes: isolated terminal primary amine functionalities bonded to silicon atoms of the microporous framework; or silazane functionalities, wherein the nitrogen atom of the silazane bridges two silicon atoms of the microporous framework; or both.
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 29/08 - Crystalline aluminosilicate zeolitesIsomorphous compounds thereof of the faujasite type, e.g. type X or Y
Low grade waste heat is captured in a gas-oil separation plant (GOSP). Heat is transferred from a first hydrocarbon gas stream to a first portion of a mixed refrigerant stream to vaporize the first portion. Heat is transferred from a first portion of a mixture of the first hydrocarbon gas stream and a second hydrocarbon gas stream to a second portion of the mixed refrigerant stream to vaporize the second portion. Heat is transferred from a second portion of the mixture to a third portion of the mixed refrigerant stream to vaporize the third portion. A combined stream, including the vaporized first, second, and third portions, is flowed through a turbine-generator. Flowing the combined stream through the turbine-generator causes a rotor of the turbine-generator to rotate. Electrical power is generated in response to rotation of the rotor. The combined stream is condensed to reform the mixed refrigerant stream.
A method to determine locations of new wells that includes receiving grid data (e.g., data sets (208)) for a region containing a hydrocarbon reservoir and discretizing the region into a plurality of blocks. The method further includes receiving optimization parameters (236) that include at least one production objective (238), where the production objective (238) specifies a desired hydrocarbon production from the hydrocarbon reservoir over a period of time and determining a deliverability magnitude for each block in the plurality of blocks, where the deliverability magnitude is based on a permeability and a net pay for each block. The method further includes proposing one or more proposed well locations based on the deliverability magnitude, forecasting the production through time of the one or more proposed well locations, and selecting and scheduling one or more proposed well locations to meet the at least one production objective (wellsite schedule (250)).
A robotic crawler for back purging a weld location in a piping circuit includes a body, one or more conveyors coupled to the body for transporting the robotic crawler within the piping circuit, first and second seal assemblies configured to generate an interference seal with an interior of the piping circuit, a pair of extendable arms, each extendable arm supporting a respective one of the first and second seal assemblies on an opposite side of the body, each respective extendable arm selectively extendable and retractable with respect to the body to adjust a position of the respective seal assembly with respect to the body, and an inert gas flow valve for providing an inert gas into a sealed area defined between the first and second seal assemblies.
The present invention provides a method of analyzing a hydrocarbon sample, comprising determining a representative composition of each of two or more portions of the sample, wherein each representative composition independently comprises one or more representative species; determining a mass fraction of each of the two or more portions present in the sample; and determining a mass fraction of each representative species present in each of the two or more portions of the sample. Each representative species is defined by a number of carbon atoms, a number of alkyl-chain carbon atoms, a number of saturated rings; a number of aromatic rings, and a number of sulfur atoms.
A system (200) and method include a dart deployment sub (202) coupled to a drill string (150) including a data receiver (206), a transmission device (208), and a data transmission cable (210), a downhole data collection sub (216) coupled downhole from the dart deployment sub (202) including an instrumentation package (212) capable of acquiring parameter data regarding a location (220) in the wellbore, and a dart (214) disposed inside the dart deployment sub (202) coupled to the data transmission cable (210) configured to receive acquired parameter data from the downhole data collection sub (216). The dart (214) is configured to depart from the dart deployment sub (202) and land in the downhole data collection sub (216), wherein the data receiver (206) is configured to receive parameter data from the dart (214) via the data transmission cable (210). The system further includes a surface collection device (160) coupled to the transmission device (208) configured to transmit parameter data from the dart deployment sub (202) to the surface collection device (160).
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 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
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A digital supply chain twin system includes a transceiver and a processor, The transceiver receives supplier inventory data specifying parts forming products to initiate, maintain, or use a wellbore. The processor executes a drilling operations module (43), a materials module (49), a workflow module (55), and a demand quantity prediction module (51), which form a supply chain twin platform (21). The drilling operations module (43) stores scheduling data of wellsite procedures. The materials module (49) stores information specifying parts necessary for the manufacturer to build products, and determines a quantity of products built thereby. The workflow module (55) determines manufacturer inventory information specifying available products, and a moving average representing products built during a predetermined time period. The demand quantity prediction module (51) predicts a forecast quantity of products built prior to the scheduled date. The drilling operations module (43) reschedules the wellsite procedures when the requisite quantity is greater than the forecast quantity of products for the scheduled date.
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
G06Q 10/0631 - Resource planning, allocation, distributing or scheduling for enterprises or organisations
G06Q 10/087 - Inventory or stock management, e.g. order filling, procurement or balancing against orders
67.
WATER OIL SEPARATOR VESSEL WITH HYDROPHOBIC MESH TUBES
Systems and a method for oil-in-water are provided. A water-oil separation plant (WOSEP) includes a gravity separation vessel, an inlet for an oil-in-water emulsion, an oil outlet for separated oil, a water compartment in the gravity separation vessel, and a water outlet from water compartment for separated water. A tube of hydrophobic mesh with an axis perpendicular to the water surface is disposed in the water compartment, wherein the top of the tube is above the water surface, and the bottom of the tube is below the water surface. An outlet coupled to the bottom of the tube allows oil and water to drain from the tube.
A method may include determining cycle-slip error data using a cycle-slip error detection technique and a first set of positioning signals. The method may further include determining multipath error data using a multipath error detection technique and the first set of positioning signals. The method may further include determining whether the positioning satellites (141, 145) satisfy a predetermined criterion based on the cycle-slip error data and the multipath error data. The method further includes determining a second set of positioning satellites in response to determining that the first set of positioning satellites fail to satisfy the predetermined criterion. The first set of positioning satellites may be different from the second set of positioning satellites. The method may further include obtaining a second set of positioning signals using the second set of positioning satellites. The method further includes determining position data using the second set of positioning signals.
A downhole fishing tool for retrieving an object from a wellbore includes a main body assembly configured to be positioned in the wellbore, a cladding material disposed on an edge of a downhole end of the main body, and a lens configured to direct a laser beam along the cladding material when the cladding material is in contact with the object, thereby welding the fishing tool to the object such that, when welded, pulling the tool in an uphole direction pulls the object along with the fishing tool.
A downhole fishing tool for retrieving an object from a wellbore includes a main body assembly, one or more nozzles configured to dispose a cladding powder on the object when the object is proximate to the tool, and one or more lenses configured to direct a laser beam at the cladding powder disposed on the object, thereby welding the fishing tool to the object such that pulling the tool in an uphole direction pulls the object along with the fishing tool.
An inventory management device includes a transceiver and a processor, The transceiver receives existing inventory information specifying parts required to build a product for a wellsite procedure. The processor executes a forecasting module (71), an outlier module (73), a scheduling module (79), an averaging module (75), and an inventory management module (77), which form a demand quantity prediction unit. The forecasting module (71) adds the existing inventory information to an Al database that stores inventory data of historically available parts and products. The outlier module (73) creates filtered inventory data by removing statistically abnormal information from the inventory data of the Al database. The forecasting module (71) determines an available quantity of parts from a moving average of the filtered inventory data computed by the averaging module (75). The inventory management module (77) places an order for parts based upon a difference between the forecast available and required quantities of parts for a scheduled date stored in the scheduling module (79).
This disclosure relates to methods of thermal carbonization, including heating a petroleum feedstock and a carbonization catalyst to form a sulfur-doped carbon product.
C01B 32/05 - Preparation or purification of carbon not covered by groups , , ,
B01J 20/20 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising free carbonSolid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising carbon obtained by carbonising processes
B01J 20/30 - Processes for preparing, regenerating or reactivating
C10B 57/06 - Other carbonising or coking processesFeatures of destructive distillation processes in general using charges of special composition containing additives
C10G 11/02 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils characterised by the catalyst used
C10B 57/14 - Features of low-temperature carbonising processes
C10B 57/16 - Features of high-temperature carbonising processes
C10G 1/08 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by destructive hydrogenation with moving catalysts
73.
ACTION-ORIENTED MONITORING SYSTEM FOR ROTATING EQUIPMENT
A method for controlling a pump system, the method comprising: receiving, from a flow sensor, flow data representing fluid flow at an input of a pump in a pump system, the pump system comprising a recycle line configured to redirect flow from an output of the pump to the input of the pump; determining, based on the flow data, configuration data specifying a hardware configuration of the pump system, and a model specifying a performance history of the pump system, that a recycle event is occurring or about to occur; and generating, based on the determining, an alert comprising a recommendation for a remedial action to reduce an amount of fluid flow through the recycle line during the recycle event relative to a baseline amount of fluid flow through the recycle line.
An assembly and a method for determining a lifetime expectancy of the electrical submersible pump. An assembly includes a motor, a motor head coupled to the motor, a power cable, a sensor module, and a local controller. The motor head has one or more toroidal transformers. The power cable extends into the motor head through the toroidal transformers to the motor. The sensor module receives power from toroidal transformers, detects a condition of the motor, and transmits a signal representing the condition of the motor. The local controller receives electrical power from the toroidal transformers; receives the signal representing the condition of the motor; based on the condition of the motor, determines a mass flow rate of the motor; and based on the mass flow rate of the motor, determines a life expectancy of the motor.
A downhole tool for repairing a tubular disposed in a wellbore includes a main body assembly configured to be positioned within the tubular, a cladding feed assembly configured to dispose a cladding material on an interior surface of the tubular, and a laser head assembly configured to direct a laser beam towards the cladding material disposed on the interior surface to thereby weld at least a portion of the cladding material to the interior surface the laser head assembly further configured to selectively adjust an area of the laser beam incident on the cladding material disposed on the interior surface of the tubular.
Methods and systems provide secure, real-time software updates over a public network to an isolated security system. A method includes the steps of setting up a network address translation (NAT) data structure for allowing outbound connections only through a first firewall between the isolated security system and the public network, and configuring the isolated security system to identify an internet web gateway address to get a software update from a security system update manager over a predetermined protocol and port. A further step involves configuring a proxy setting in the isolated security system to identify an internet web gateway address of a proxy server in a NAT subnet.
An inner surface of a thermosyphon reboiler is engraved. The thermosyphon reboiler includes a first side configured to receive a liquid and a second side configured to receive a heating fluid. The thermosyphon reboiler is configured to transfer heat from the heating fluid at the second side to the liquid at the first side to boil the liquid at the first side. Engraving the inner surface of the thermosyphon reboiler includes engraving a pattern across at least a portion of an inner surface of the first side of the thermosyphon reboiler. The pattern has a specified depth that increases a heat transfer surface area of the first side of the thermosyphon reboiler. The engraved pattern prevents film boiling from occurring at the inner surface of the first side of the thermosyphon reboiler.
F28F 1/12 - Tubular elements or assemblies thereof with means for increasing heat-transfer area, e.g. with fins, with projections, with recesses the means being only outside the tubular element
F28F 13/18 - Arrangements for modifying heat transfer, e.g. increasing, decreasing by applying coatings, e.g. radiation-absorbing, radiation-reflectingArrangements for modifying heat transfer, e.g. increasing, decreasing by surface treatment, e.g. polishing
78.
FACIES CLUSTERING FOR SUBTERRANEAN PROPERTY MODELING AND WELL PLACEMENT
The present disclosure relates to methods and apparatuses for determining subterranean properties of a reservoir. An example method includes receiving log data for a plurality of wells in the reservoir, the log data representing at least one petrophysical property of a subsurface of the reservoir for the plurality of wells, generating multiple facies clusters based on the log data, determining one or more neighbor wells for each of the plurality of wells based on geographic locations of the plurality of wells, and for each of the plurality of wells, determining that the well is within a threshold distance of a facies cluster boundary upon determining that the well and a neighbor well of the well are represented by different facies clusters.
The present disclosure relates to methods for petrochemical production integrating a slurry phase hydrocracking process and an inline hydrotreating process. A slurry-phase hydrocracking feed comprising residue stream and/or a deasphalted residue stream is processed in a slurry-phase hydrocracking reaction zone to produce slurry-phase hydrocracking effluents. A first stream of slurry-phase hydrocracking effluents is discharged including unreacted hydrogen and which is under hydrogen partial pressure. The slurry-phase hydrocracking effluents are processed in an inline hydrotreating zone for hydrodesulfurization and/or hydrodenitrogenation to produce a hydrotreated effluent. Downstream FCC and petrochemicals production complex units are used to produce light olefins and aromatic products.
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 21/00 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbonsHydrofinishing
C10G 47/26 - Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, to obtain lower boiling fractions with moving solid particles suspended in the oil, e.g. slurries
C10G 69/04 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
C10G 69/06 - Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of thermal cracking in the absence of hydrogen
80.
SYSTEM AND METHOD FOR AUTOMATIC WELL INTEGRITY LOG INTERPRETATION VERIFICATION
Systems and methods for automatic well integrity log interpretation verification are disclosed. The methods include obtaining a first dataset comprising casing thickness profiles and associated electromagnetic [EM]data from at least a first hydrocarbon well having a casing; selecting a training dataset using at least a subset of the casing thickness profiles and a subset of the associated EM data; and training, using the training dataset, a machine learning network to produce a predicted corrosion log of a target section of a second hydrocarbon well from measured EM data from the second hydrocarbon well.
Method and systems for generating a reservoir simulation grid (300) for a subterranean reservoir are disclosed. The method may include, using a reservoir simulation system (120), to obtain a reservoir model (202), where the reservoir model (202) comprises a plurality of wellbore trajectories, define a coarse simulation grid pertaining to, at least a portion, of the reservoir model (202), and determine a grid refinement field based, at least in part, on the reservoir model (202). The method may further include, using a reservoir simulation system (120), to form a tree (400) based on the coarse simulation grid, refine the tree (400) at least in part, on an intersection of the grid refinement field and the coarse simulation grid, and define the reservoir simulation grid (300) based, at least in part, on the refined tree (400) and the coarse simulation grid.
Mineralizing carbon dioxide for storage may occur in a wellbore. For example, a method of mineralizing carbon dioxide may include: introducing, through a first wellbore to a subterranean formation, a first solution including a metal salt and a metal catalyst; introducing a second solution including a brine, wherein the second solution has nanobubble carbon dioxide at least partially dispersed therein, and wherein the second solution is introduced after introduction of the first solution; injecting carbon dioxide gas thereby at least partially dispersing the carbon dioxide gas in the first solution, thereby forming dissolved carbon dioxide; generating mineralized carbon dioxide from the dissolved carbon dioxide, wherein the generating includes catalytically reacting the metal salt and the dissolved carbon dioxide using the metal catalyst, thereby forming the mineralized carbon dioxide; and depositing the mineralized carbon dioxide within the subterranean formation.
A method for subsurface hydrogen storage and hydrogen retrieval. The method includes identifying a subsurface formation [30] (step 100). The method further includes selecting a liquid organic hydrogen carrier (LOHC) feed [10] compatible with the subsurface formation [30] (step 110). The LOHC feed [10] includes a mixture of one or more completely or partially hydrogenated LOHCs. The LOHC feed [10] is injected into the subsurface formation [30] (step 120) for storage (step 130). Later, when needed, the LOHCs are recovered from storage [13] (step 140), optionally separating a recovered water/brine phase [15] and off gas [16] from the LOHCs from storage [13/14] in a separator [21] configured to produce a stream of recovered LOHCs [13] (step 150). The recovered LOHC [13] is then dehydrogenated to form a H2 product [17] and dehydrogenated LOHCs [18] in a dehydrogenation unit [22] process (steps 180 and 190).
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Saudi Arabia)
ARAMCO SERVICES COMPANY (USA)
Inventor
Sabate, Jorge, Gascon
Ribeiro Gallo, Jean, Marcel
Abstract
A composition of an indium oxide catalyst including an alkali dopant and a method for producing an indium oxide catalyst including an alkali dopant. The alkali dopant may include a cation of Li +, Na+, K+, Rb+, Cs+, and Fr+. The method for producing the indium oxide catalyst including an alkali dopant includes mixing a solution of an indium salt with a base to form precipitated indium hydroxide (100), contacting the precipitated indium hydroxide with a solution including an alkali metal salt to produce an indium hydroxide solution (102), and calcinating the indium hydroxide solution to form indium oxide; thereby forming the indium oxide catalyst including an alkali dopant (104).
A method of producing refractory brick includes heating a spent Claus catalyst, reducing a particle size of the catalyst, dry mixing the catalyst with cement to form a dry mixture, adding water to the dry mixture to form a castable mixture, casting the castable mixture in a mold, curing the mold, and drying the mold to form the refractory brick.
A wastewater stream is flowed from a separator to an anode side of a microbial electrolysis cell (MEC). The wastewater stream includes water and hydrocarbons. The separator is positioned in a gas-oil separation plant. The MEC electrolyzes the hydrocarbons to produce hydrogen ions. A membrane separates the MEC into the anode side and a cathode side. The membrane allows the hydrogen ions and water molecules to pass through the membrane from the anode side to the cathode side, thereby forming a treated wastewater stream at the cathode side. The MEC combines the hydrogen ions at the cathode side to produce hydrogen gas. The treated wastewater stream and a hydrogen gas stream is discharged from the cathode side. The hydrogen gas stream includes the hydrogen gas produced by the MEC. The hydrogen gas stream is oxidized into water. Electrical power is generated in response to oxidizing the hydrogen gas into water.
C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities
C02F 103/36 - Nature of the water, waste water, sewage or sludge to be treated from the chemical industry not provided for in groups from the manufacture of organic compounds
A method for evaluating and controlling a washout region of a wellbore placed in a formation includes: obtaining information about the wellbore and the formation; establishing a washout indicator function as a function of time and location; computationally determining whether the washout region exists by calculating the washout indicator function on a cross section of the wellbore and the formation, at each depth in a specific depth range; and upon finding presence of the washout region in the specific depth range, quantifying the washout region. The washout indicator function returns: a negative value for a point within the formation; a positive value for a point within the washout region; and zero for a point on a boundary.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
E21B 47/08 - Measuring diameters or related dimensions at the borehole
88.
SYSTEM AND METHOD TO ACCELERATE CORE IMAGES ACQUISITION AND PROCESSING USING MACHINE LEARNING
A method for analyzing rock cores of a subterranean formation is disclosed. The method includes capturing low resolution core images of the rock cores, selecting, by a computer processor and based on a pre-determined quality threshold for qualifying the low resolution core images, a number of qualified rock cores, capturing high resolution core images of the qualified rock cores, generating, by the computer processor and based on a high resolution core image evaluation model, a ranking of the qualified rock cores, and analyzing, based at least on the ranking, the qualified rock cores to generate a core analysis result.
A method and a system for generating a labeled benchmark dataset are disclosed. The method includes obtaining a plurality of sources related to a thin section using web scraping and extracting a plurality of images from the plurality of sources related to the thin section, the plurality of images including a plurality of thin section images and a plurality of non-thin section images. Further, the method includes determining the plurality of thin section images from the plurality of extracted images and generating a classification of the plurality of thin section images based on a given classification criteria. The geological thin-section based machine learning models is trained based on the generated classification of the plurality of thin section images and a wellbore drilling plan is generated based on the geological thin-section based machine learning models.
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
G06V 20/70 - Labelling scene content, e.g. deriving syntactic or semantic representations
90.
METHOD FOR EVALUATING AND RANKING THE ENHANCED RECOVERY POTENTIAL FOR UNCONVENTIONAL RESERVOIRS
A method to perform a field operation of an unconventional reservoir is disclosed. The method includes selecting, from rock samples and based on test reports of corresponding companion rock samples, selected rock samples representing rock characteristics of formation zones in the unconventional reservoir, performing, using a rock sample test apparatus, a sequence of rock sample test cycles on each selected rock sample to generate rock sample test results, generating, based on the rock sample test results, a ranking of the selected rock samples representing enhanced oil recovery (EOR) potential of the formation zones, selecting, from the formation zones and based on the ranking, a target formation zone having an EOR potential meeting a pre- determined criterion, and performing, based at least on the EOR potential of the target formation zone, the field production of the unconventional reservoir.
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Implementations of the present disclosure include a wellbore assembly that includes a wellhead assembly and a plunger. The wellhead assembly is coupled to a wellbore string disposed within a wellbore. The wellhead assembly includes a lubricator, a spring, and a flexible damper. The lubricator defines a tubular housing. The spring is disposed at least partially within and attached to the tubular housing. The spring comprises a first end attached to the tubular housing. The flexible damper is coupled to a second end of the spring opposite the first end. The plunger strikes, as the plunger is lifted from a downhole location of the wellbore to the terranean surface, the flexible damper. The flexible damper deforms, upon impact with the plunger, to dissipate some or all of the kinetic energy of the plunger.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/12 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having free plunger lifting the fluid to the surface
Carbon dioxide may be stored by mineralization. An example method thereof may include: providing a first solution (111) including a first aqueous fluid (112) having dispersed therein a metal salt (114) and a metal catalyst (116); dispersing carbon dioxide gas (134) in a second solution (131) including a second aqueous fluid (132), wherein the carbon dioxide gas forms dissolved carbon dioxide (134d); introducing an electrical current (138e) to the second solution; generating, using the electrical current, nanobubble carbon dioxide (134n): combining at least a portion of the first solution and at least a portion of the second solution to form a combined solution; and generating mineralized carbon dioxide from the dissolved carbon dioxide and the nanobubble carbon dioxide, wherein the generating at least partially comprises catalytically reacting, using the metal catalyst, the metal salt and one or more of the dissolved carbon dioxide and the nanobubble carbon dioxide, thereby forming the mineralized carbon dioxide.
A method includes lifting a first plunger within a production string disposed within a wellbore. The production string divides the production string into multiple stages. The plunger landing assemblies include a first landing assembly and an intermediate landing assembly. The lifting includes lifting the first plunger in a first stage to lift production fluid accumulated uphole of the first plunger. The method also includes continuing to lift the first plunger until the first plunger strikes the intermediate one of the plurality of landing assemblies, allowing the production fluid to flow past the second one of the plurality of landing assemblies into a second stage. The method also includes securing the first plunger and lifting, with the production fluid accumulated uphole of a second plunger residing in the second stage, the second plunger to lift the production fluid toward the wellhead.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/12 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having free plunger lifting the fluid to the surface
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 polyester methylene phosphonic acid (PAPEMP) and amino tris-methylene 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.
A method of preparing an enhanced oil recovery composition is described. The method includes carbonizing (200) a biomass waste material (202) to provide carbon microparticles (208). The method includes functionalizing (300) the carbon microparticles (208) through an acid treatment such that the carbon microparticles have a hydrophilic surface (306). The method further includes grinding (400) the carbon microparticles to provide carbon nanoparticles (406), where the carbon nanoparticles have a hydrophilic surface (306) and a hydrophobic surface (404). A method of enhanced oil recovery is also described.
C09K 8/03 - Specific additives for general use in well-drilling compositions
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
A laser cutting tool (400) includes a tool body (402) having a central axis (504); a laser cutting head (404) provided coaxially along the central axis (504) of the tool body; and a laser head (408) disposed on a side of the laser cutting head (404). The laser head (408) includes a laser exit. An internal laser passageway (508) extends in a radial direction between the laser cutting head (404) and the laser exit configured to direct a laser beam (206) from the laser cutting head (404) in a radially outward direction through the laser exit. A plurality of internal nozzles (406) positioned within the laser head (408) configured to direct a cooling substance to a cutting area around the laser beam (206) and a plurality of adjacent cutting zones around the cutting area (300). The plurality of internal nozzles (406) are arranged parallel to the internal laser passageway (508).
A system (1) for monitoring fluid flow conditions on a return flow line (6) including a return flow line (6) in fluid communication with a wellbore, a shaker (5), and a header box (7). The system (1) includes a contactless flow sensor (15) facing an interior of the header box (7) or an outlet of the return flow line (6), a data gathering and analyzing unit (2) coupled to the contactless flow sensor (15), and a control panel (3) to display data and notify when hazardous conditions occur. A method for monitoring fluid flow conditions on a return flow line (6) including flowing a drilling mud into the header box (7) through the return flow line (6) and monitoring the height of the drilling mud in the header box (7) and/or return flow line (6) to determine the fluid level using the contactless flow sensor (15). The fluid level is used to determine a fluid flow rate and indicate a current operational or a hazardous operational status.
An untethered device (100) includes a tool (200) and a ballast weight (206). The ballast weight (206) includes an attachment plate (216) that is securable to the tool (200), a dissolvable ballast (210), and attachment elements (208) that secure the dissolvable ballast (210) to the attachment plate (216). At least one of the attachment elements (208) is dissolvable to release the dissolvable ballast (210) from the attachment plate (216).
An autonomous robot (200) for descaling a pipeline (102) includes a streamlined housing (202); a propulsion system at least partially enclosed in the streamlined housing and including a power source (214) and a motor (216), where the propulsion system is configured to move the housing through a pipeline (102) that includes scale (104); a flow turbine (212) coupled to the power source (214) and configured to generate electrical power based on a flow of water in the pipeline (102) through the flow turbine (212) as the housing (202) moved through the liquid in the pipeline (102); and a scale removal sub-assembly (208) including a plasma tool (300) configured to generate plasma near the scale (104) to remove at least a portion of the scale (104) from an inner surface (103) of the pipeline (102).
B08B 9/049 - Cleaning the internal surfacesRemoval of blockages using cleaning devices introduced into and moved along the pipes having self-contained propelling means for moving the cleaning devices along the pipes
B08B 7/00 - Cleaning by methods not provided for in a single other subclass or a single group in this subclass
100.
METHOD TO DESIGN SALT CAVERN FOR CYCLICAL WITHDRAWAL OF GAS
Methods and systems include obtaining a correlation and obtaining a salt sample from a salt formation. The methods and systems further include, for each of N cycles, exposing, using an injection system, the salt sample to an nth amount of a gas and determining an nth value of a property by subjecting the salt sample, using an atomic force microscopy (AFM) system, to an AFM test. The methods and systems further include determining a relationship using the N values of the property, determining, using the correlation, a macroscale relationship based on the relationship, and generating a fit constitutive model by fitting the constitutive model to the macroscale relationship. The methods and systems include generating a model of a salt cavern within the salt formation based on the fit constitutive model and designing a salt cavern for withdrawal cycles of the gas using the model.
patents
