petroleum industry equipment, namely, fluids processing equipment used for solids control, namely, shaker screens, shakers, desanders, desilters, hydroclone packages being several hydroclones connected by piping and mounted on a skid; mud cleaners being hydroclones used in conjunction with a shaker, all of which is mounted on a skid; centrifuges and fluids processing systems, namely, an integrated, tailor-made system consisting of two or more primary shakers, a desander, a desilter, a hydroclone package, a mud cleaner, a centrifuge, a degasser and associated piping and tanks mounted on a skid; pressure control equipment, namely, chokes, degassers, centrifugal degassers, hydrogen sulfide mud-gas separators, dual mud gas separators for horizontal drilling; total gas containment systems, namely, integrated degasser and hydrogen sulfide mudgas separator with associated valves and piping mounted on either a skid or a trailer
A tool includes an internal assembly configured to be positioned at least partially within a body. The tool also includes a collet configured to be positioned at least partially within the body and axially-adjacent to the internal assembly. The collet includes a plurality of fingers that are circumferentially-offset from one another. At least one of the fingers includes a protrusion that extends radially-outward and is configured to be positioned at least partially within a recess formed in an inner surface of the body to secure the collet in place with respect to the body. The tool also includes a collet pin configured to be positioned at least partially within the body, axially-adjacent to the internal assembly, and at least partially within the collet. The collet pin is configured to contact the internal assembly to secure the internal assembly in place within the body.
Corrosion inhibition compositions and methods useful for inhibiting corrosion are provided. The corrosion inhibition compositions comprise at least one filming agent and at least one promoting agent and the methods for inhibiting corrosion on metal surfaces utilize the disclosed corrosion inhibiting compositions.
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C23F 11/04 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in markedly acid liquids
5.
COUPLING AGENTS FOR USE IN CORROSION INHIBITING COMPOSITIONS
Corrosion inhibition compositions and methods useful for inhibiting corrosion are provided. The corrosion inhibition compositions comprise at least one coupling agent and at least one corrosion inhibitor, wherein the at least one coupling agent is at least one of one or more ether amines, one or more ether amine oxides, and at least one combination thereof, and the at least one corrosion inhibitor is at least one selected from one or more thiophosphates, one or more polyphosphate esters, one or more imidazolines, one or more quinolines, one or more alkynols, one or more alkynol derivatives, and at least one combination thereof. The methods for inhibiting corrosion on metal surfaces utilize the disclosed corrosion inhibiting compositions.
C23F 11/04 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in markedly acid liquids
E21B 41/02 - Equipment or details not covered by groups in situ inhibition of corrosion in boreholes or wells
A system includes a fluid conduit, a fluid chamber in communication with the fluid conduit, a rheology sensor in communication with the fluid chamber, and an electric temperature controller in communication with the fluid chamber. The fluid chamber is cooled or heated in response to a first control signal from the electric temperature controller.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 36/04 - Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
E21B 36/00 - Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
A lock assembly for a vibratory separator includes a latch. The latch includes a first inner protrusion and a first outer protrusion. The first outer protrusion defines a first outer protrusion opening. The lock assembly also includes a first spacer. The first spacer includes a first fastener that is configured to be inserted into the first outer protrusion opening.
A system for separating components from a slurry of drilling fluid and drill cuttings on a shaker screen having an upper side and a lower side within a shaker. The system also has a pressure differential generator to pull an effective volume of air through a section of the shaker screen to enhance the flow of drilling fluid through the section of the shaker screen and the separation of drilling fluid from drill cuttings and further maintain an effective flow of drill cuttings off the shaker. A method of separating components of a slurry of drilling fluids and solids has the steps of delivering the slurry to a shaker, flowing the slurry over a first screen and applying an effective amount of vacuum to a first portion of the first screen to remove the drilling fluids from the slurry without stalling the solids on the first screen.
B01D 33/03 - Filters with filtering elements which move during the filtering operation with translationally moving filtering elements, e.g. pistons with vibrating filter elements
B01D 33/72 - Filters with filtering elements which move during the filtering operation having feed or discharge devices for feeding
A bob for a viscometer in a portable rheology unit is provided. The bob may include a bob portion having a cylindrical portion and a first end portion, the cylindrical portion defining a first end of the bob. The bob may also include a plastic portion interfacing with an interior surface of the first end portion, wherein the plastic portion includes a conical area extending from a conical area first end to a conical area second end, and the conical second end is connected to an interior surface of the cylindrical portion. The bob may also include a sleeve portion connected to the plastic portion and a bob second end portion connected to the sleeve portion.
G01N 11/14 - Investigating flow properties of materials, e.g. viscosity or plasticityAnalysing materials by determining flow properties by moving a body within the material by using rotary bodies, e.g. vane
A screen assembly includes a filter media and a frame coupled to the filter media. The frame includes an inner portion and an outer portion. The inner portion of the frame is configured to be coupled to a stabilizing member. The screen assembly is configured to be positioned in a vibratory separator and to vibrate within the vibratory separator. The stabilizing member is configured to facilitate the inner portion of the frame vibrating substantially uniformly with the outer portion of the frame.
Systems and methods for a screen assembly configurable in a multi-screen configuration. The screen assembly in the multi-screen configuration includes a lower shaker screen and an upper shaker screen. A track is configured to be disposed on an inside wall of a vibratory separator and includes an upper retainer and a lower retainer. A screen clamping assembly is disposed in the track and includes a small spacer disposed between the lower shaker screen and the upper shaker screen in the track when the screen assembly is in the multi-screen configuration. An actuator is disposed in the track and has a clamped position where the actuator is actuated to provide a clamping force to clamp the lower shaker screen, the upper shaker screen, and the small spacer between the upper retainer and the lower retainer of the track.
B01D 33/03 - Filters with filtering elements which move during the filtering operation with translationally moving filtering elements, e.g. pistons with vibrating filter elements
B07B 1/28 - Moving screens not otherwise provided for, e.g. swinging, reciprocating, rocking, tilting, or wobbling screens
B07B 1/46 - Constructional details of screens in generalCleaning or heating of screens
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
An apparatus for agitating a slurry mixture in a vibratory shaker including a bar blank with a top surface and a bottom surface; and at least one protrusion extending away from the top surface of the bar blank, where the at least one protrusion is configured to agitate the slurry mixture as the slurry mixture passes around the at least one protrusion.
A method of installing a vibratory shaker screen in a vibratory shaker, including placing a first end of the vibratory shaker screen in a retainer, wherein the retainer is one of attached and a component of the vibratory shaker; pivoting a second end of the vibratory shaker screen toward a screen installation position on the vibratory shaker, deflecting a tab on one of the vibratory shaker screen and the vibratory shaker through contact of the vibratory shaker screen to another retainer of the vibratory shaker, and connecting the vibratory shaker screen to the vibratory shaker, where the tab fixedly connects the vibratory shaker screen to the vibratory shaker.
B07B 1/28 - Moving screens not otherwise provided for, e.g. swinging, reciprocating, rocking, tilting, or wobbling screens
B07B 1/46 - Constructional details of screens in generalCleaning or heating of screens
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B01D 33/03 - Filters with filtering elements which move during the filtering operation with translationally moving filtering elements, e.g. pistons with vibrating filter elements
14.
ADDITIVES TO TEMPORARILY REDUCE VISCOSITIES IN OIL-BASED FLUIDS
Additives configured to temporarily reduce viscosity in oil-based fluids are provided. The additives may be a reaction product of at least one non-ionic additive and at least one acid anhydride of maleic, succinic and/or glutaric acid. The at least one non-ionic additive may be selected from linear or branched alcohols, alcohol ethoxylates, a combination thereof, and/or a derivative thereof.
Vibratory separators and methods are provided. One vibratory separator may include a housing, a drilling material inlet, at least one upper screen assembly and at least one lower screen assembly disposed in the basket at a feed end of the basket and in fluid communication with the drilling material inlet, an actuator connected to the basket and configured to provide vibratory motion to the basket, and a sump configured to receive drilling material that passes through the at least one upper screen assembly and the at least one lower screen assembly. The vibratory separator may also include a first fluid flow path from the at least one upper screen assembly to the sump and a second fluid flow path from the at least one lower screen assembly to the sump, wherein the length of the first fluid flow path is greater than the length of the second fluid flow path.
Branched and crosslinked polymeric fluid loss control agents and methods are provided that have at least one acrylamide-based monomer, at least one sulfonated anionic monomer, and at least one crosslinking monomer. The at least one acrylamide-based monomer and the at least one sulfonated anionic monomer are crosslinked. The branched and crosslinked polymeric fluid loss control agents have between 50 and 99 mol % of the at least one acrylamide-based monomer, between 1 and 30 mol % of the at least one sulfonated anionic monomer, and between 0.1 and 10 mol % of the at least one crosslinking monomer.
The present disclosure relates to compositions and methods for prevent the formation of and disperse aggregates and other poorly soluble materials in hydrocarbon fluids. The compositions include an asphaltene dispersant prepared from the reaction of a polyethyleneimine (PEI) dendrimer and one or more derivatizing reagents wherein the polyethylene dendrimer has a weight average molecular weight of greater than or equal to 9 kDa. The methods include emplacing in a wellbore a composition comprising an asphaltene inhibitor, wherein the asphaltene inhibitor is a compound prepared from the reaction of a polyethyleneimine dendrimer and one or more derivatizing reagents wherein the polyethylene dendrimer has a weight average molecular weight of greater than or equal to 9 kDa.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
18.
ENVIRONMENTALLY FRIENDLY FLOW IMPROVERS WITH IMPROVED FORMULATION STABILITY AT LOW TEMPERATURES
A method of treating petroleum fluids may include adding a flow improver composition to the petroleum fluids, the flow improver composition, comprising: a solvent; and a dendrimer-based flow improver, wherein at least a portion of the surface sites of the dendrimer are chemically modified with saturated and unsaturated fatty acids.
Wellbore fluids may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; and a polymeric amidoamine emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the polymeric amidoamine emulsifier has at least 5 repeating units. Wellbore fluids may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; and a polymeric amidoamine emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the polymeric amidoamine emulsifier includes at least 3 repeating units selected from allylamine, polyaminopolyamide, N-alkyl acrylamides, (meth)acrylic acid, alkyleneamine reacted with a dicarboxylic acid, alpha-olefin-alt-maleic anhydride, styrene maleic anhydride, alkylene oxide, wherein one or more amine or acid group on the repeating unit is amidized.
A method of breaking a filtercake in a wellbore may include circulating a breaker fluid into the wellbore having a filtercake on the walls thereon, the filter cake including copolymer formed from at least one acrylamide monomer and at least one sulfonated anionic monomer, the breaker fluid comprising: a base fluid; a mixture of hydrolysable esters of dicarboxylic acids; and an organic peroxide oxidant.
Rheometer systems and related methods are provided. In accordance with an example, a rheometer system includes a rheometer and a platform supporting the rheometer and movable between a lowered position and a raised position. The rheometer system includes a fluid receptacle defining an opening. The rheometer system includes a receptacle housing having a housing side and adapted to receive the fluid receptacle. The opening of the fluid receptacle facing the rheometer when the fluid receptacle is received by the receptacle housing. The rheometer system includes a thermoelectric device coupled adjacent to the housing side. The rheometer system includes a controller in communication with the thermoelectric device and adapted to control a temperature of the thermoelectric device.
G01N 11/02 - Investigating flow properties of materials, e.g. viscosity or plasticityAnalysing materials by determining flow properties by measuring flow of the material
G01N 11/00 - Investigating flow properties of materials, e.g. viscosity or plasticityAnalysing materials by determining flow properties
A wellbore fluid may include an oleaginous fluid forming a continuous phase; a non-oleaginous fluid forming a discontinuous phase; at least one emulsifier stabilizing an emulsion of the non-oleaginous continuous phase within the oleaginous continuous phase; and at least one viscosifier dispersed into the oleaginous continuous phase in a concentration of at least 4 ppb; wherein upon subjecting the wellbore fluid to shear rate of at least 10,000 s-1, the emulsion is disrupted and the non-oleaginous fluid contacts the at least one viscosifier, thereby solidifying the wellbore fluid.
A method of drilling a wellbore may include drilling the wellbore using a wellbore fluid that has rheological property values for 6rpm, 10 minute gel, Yield Point, and/or 10 minute-to-10 second gel ratio that are +/ 20% of the mean values across a temperature range from 40°F to 300°F; and conditioning the wellbore with less than 2 hole volumes. The wellbore fluid may include an oleaginous external phase; a non-oleaginous internal phase; an amidoamine emulsifier stabilizing the non-oleaginous internal phase within the oleaginous external phase; at least two oil wetting agents; a rheology modifier; and a weighting agent having a d50 ranging from 5 to 10 µm.
A wellbore fluid may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier stabilizing the non-oleaginous phase within the oleaginous phase; a low density material selected and in an amount to result in a specific gravity of the wellbore fluid that is less than 0.83; and at least one rheology modifier selected to suspend the low density material within the wellbore fluid.
A method of recycling a direct emulsion wellbore fluid may include disrupting a direct emulsion comprising an aqueous external phase and an oleaginous internal phase, wherein the direct emulsion is stabilized by a surfactant composition; and separating the aqueous phase and the oleaginous phase.
A wellbore fluid is disclosed. The wellbore fluid has a non-oleaginous internal phase and an oleaginous external phase. A reversible emulsifier stabilizes the invert emulsion by pH. One or more alkanolamines are also included in the wellbore fluid.
Compositions may include an asphaltene dispersant that is the product of a reaction between a polysaccharide having at least two sugar subunits and one or more fatty acid reagents, and a petroleum fluid produced from a subterranean formation and containing asphaltenes therein. The asphaltene dispersant may have a molecular weight of at least 4000 Da. Compositions may further include an aromatic solvent. Methods may include contacting a hydrocarbon fluid with an asphaltene dispersant dissolved in an aromatic solvent, wherein the asphaltene dispersant is the product of the reaction of a polysaccharide and one or more fatty acid reagents. Methods may also include contacting a hydrocarbon fluid with an asphaltene, wherein the asphaltene dispersant is the product of the reaction of a polysaccharide and one or more fatty acid reagents and has a molecular weight of at least 4000 Da.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 43/22 - Use of chemicals or bacterial activity
28.
SYSTEMS AND METHOD FOR REMOVING DEBRIS FROM DRILLING FLUID
Systems and methods remove and/or collect magnetic debris from drilling fluid and have a sleeve with a length defined between first and second ends of the sleeve, wherein the first end of the sleeve is connectible to at least one portion of drill string. The systems and methods further have at least one fluid flow path extending through the sleeve such that the at least one fluid flow path is in fluid communication with the first portion of drill string when the sleeve is connected to the at least one portion of drill string. One or more magnetic surface areas are provided inside the sleeve such that magnetic debris in drilling fluid flowing or passing along the at least one fluid flow path is collectible at or on the one or more magnetic surface areas when the sleeve is connected to the at least one portion of drill string. The systems and methods, optional, have an interior magnetic holder having a hollow core positioned insider the sleeve, wherein the at least one portion of the at least one fluid flow path contacts an exterior surface of at least one portion of the interior magnetic holder comprising the one or more magnetic surface areas.
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
Compositions may include a corrosion inhibitor blend including: a kinetic corrosion inhibitor and a thermodynamic corrosion inhibitor, wherein the kinetic corrosion inhibitor has a rate of film formation that is at least 1.5 times greater than the respective rate of film formation of a thermodynamic corrosion inhibitor on a metal surface. Methods may include contacting a metal surface with a corrosion inhibitor composition, wherein the corrosion inhibitor composition includes: a kinetic corrosion inhibitor and a thermodynamic corrosion inhibitor, wherein the kinetic corrosion inhibitor has a rate of film formation that is at least 1.5x greater than the respective rate of film formation of a thermodynamic corrosion inhibitor on a metal surface.
A capped drilling system may include a wellbore extending through an earth formation; a drill string extending through the wellbore, terminating in a drill bit, and defining an annulus between a well of the wellbore and the drill string; a cap fluid having a density of less than 8.33 ppg in the annulus; a barrier fluid comprising an oleaginous fluid and styrenic copolymer below the cap fluid; and a drilling fluid below the barrier fluid.
C09K 8/00 - Compositions for drilling of boreholes or wellsCompositions for treating boreholes or wells, e.g. for completion or for remedial operations
E21B 33/00 - Sealing or packing boreholes or wells
A method of cleaning a wellbore prior to the production of oil or gas is disclosed, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake. The method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid includes an aqueous fluid, and imino diacetic acid or salt thereof. Optionally an acid buffering agent, and a weighting age are also included. The breaker fluid is formulated such that after a predetermined period of time and the filter cake present in the wellbore or on the wellbore face is substantially degraded. Other methods may also include drilling the wellbore with a water-based drilling mud that forms a water-based filter cake, wherein the method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid may include an aqueous fluid, and an iminodiacetic acid or a salt thereof.
A sag flow loop may include: a test section; a pump configured to at least pump fluid containing particles suspended therein at variable rates through the sag flow loop including the test section, the variable rates inducing formation of a bed of particles settled out of the fluid in the test section; and a flow meter densitometer configured to measure density of the fluid flowing through the sag flow loop. The sag flow loop may be configured to determine a sag of the particles in the fluid. The pump, the flow meter densitometer, and the test section may be connected via flowlines. The sag flow loop may have a volumetric capacity of less than four liters.
G01N 15/04 - Investigating sedimentation of particle suspensions
G01N 9/04 - Investigating density or specific gravity of materialsAnalysing materials by determining density or specific gravity by measuring weight of a known volume of fluids
An apparatus may include a centrifuge bowl rotatable about its longitudinal axis, a discharge unit positioned to receive discharge fluid from the centrifuge bowl, a diverter fluid circuit in communication with the discharge unit, a measurement region of the diverter fluid circuit with a narrower diameter than a cross section of the discharge unit, and the diverter fluid circuit oriented to direct a portion of the discharge fluid from the discharge unit to the measurement region
B04B 13/00 - Control arrangements specially designed for centrifugesProgramme control of centrifuges
B04B 3/00 - Centrifuges with rotary bowls in which solid particles or bodies become separated by centrifugal force and simultaneously sifting or filtering
An apparatus is disclosed which includes at least one feed line, a mixer including a first inlet configured to receive flow from the feed line and a second inlet configured to receive a flow from an external source, an outlet, at least one first conveyor to feed a first flow from the at least one feed hopper to the mixer, and at least one second conveyor to discharge a flow from the mixer via the outlet.
A wellbore fluid may include an aqueous base fluid, a plurality of latex particles and a coalescing agent present in the fluid in an amount effective to have an effect on decreasing the activation temperature of the latex. A method may include emplacing a wellbore fluid into a wellbore through an earthen formation, the wellbore fluid may include an aqueous base fluid, a plurality of latex particles and a coalescing agent present in the fluid in an amount effective to have an effect on decreasing the activation temperature of the latex.
A production chemical composition may include a polyether polyol; and one or more corrosion inhibitors and/or one or more scale inhibitors. A method may include injecting a composition of a polyether polyol; and one or more corrosion inhibitors and/or scale inhibitors into a production stream, which may be, for example, downhole or subsea. The polyol polyether may include, for example, ethylenedioxy(dimethanol).
C23F 11/10 - Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
This disclosure is generally drawn to systems, devices, apparatuses, and/or methods, related to monitoring a shaker used for separating solids from fluid. Specifically, the disclosed systems, devices, apparatuses, and/or methods relate to capturing infrared images of a shaker or components thereof (e.g., shaker baskets, decks, screens) and performing actions on the shaker, its components, and/or the its operation based at least in part on the captured infrared images.
A wellbore fluid may include an aqueous base fluid; a mixture of metal bromides dispersed in the aqueous base fluid; and a plurality of nanoparticles suspended in the aqueous base fluid, where the metal bromides and the plurality of nanoparticles are present in the wellbore fluid in an amount to provide a fluid density of at least 14.5 ppg (1.74 kg/L) and a true crystallization temperature of the wellbore fluid below 40°F (4.4°C). A method for completing a wellbore may include pumping a wellbore fluid into the wellbore, the wellbore fluid may include an aqueous base fluid; a mixture of metal bromides dispersed in the aqueous base fluid; and a plurality of nanoparticles suspended in the aqueous base fluid, where the metal bromides and the plurality of nanoparticles are present in an amount to provide a fluid density of at least 14.5 ppg (1.74 kg/L) and a true crystallization temperature of the wellbore fluid below 40°F (4.4°C).
A method of breaking an emulsion may include contacting an emulsion with a demulsifier, where the demulsifier is a dendrimer functionalized with a carboxylic acid derivative and separating the emulsion into two distinct phases. A method of producing crude oil may include extracting a hydrocarbon fluid from a subterranean formation; adding a demulsifier to the hydrocarbon fluid, where the demulsifier is a dendrimer functionalized with a carboxylic acid derivative; and separating the crude oil emulsion into two distinct phases.
Gravel packing compositions or fluids and/or methods pack a wellbore in a subterranean formation, wherein the wellbore comprising a cased section and an uncased section. The gravel packing compositions or fluids include gravel and a carrier fluid including an invert emulsion fluid are pumped into the wellbore, wherein the invert emulsion fluid including an oleaginous external phase having a synthetic polymer viscosifier and/or an organophilic clay viscosifier therein, a non-oleaginous internal phase, and an emulsifier stabilizing the oleaginous external phase and the non-oleaginous internal phase. When the organophilic clay viscosifier is present in the oleaginous external phase, the organophilic clay is swelled with a polar solvent that is added to the oleaginous phase prior to the addition of the organophilic clay.
A flow improver composition may include a branched dendritic core having a first quaternary carbon center bonded to four second carbon atoms, where in at least three of the four second carbon atoms are individually bonded to one or more chain extender ligands to produce the branched dendritic core, wherein the branched dendritic core has greater than or equal to about 16 terminal hydroxyl groups, wherein at least one terminal hydroxyl group is esterified with at least one carboxylic acid moiety comprising of 6 to 30 carbon atoms or a combination, and wherein the dendritic core has no nitrogen atom; a polymeric inhibitor having an alkyl side chain of 2 to 40 carbon atoms; and an aromatic solvent.
C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C08L 87/00 - Compositions of unspecified macromolecular compounds, obtained otherwise than by polymerisation reactions only involving unsaturated carbon-to-carbon bonds
A coiled tubing wellbore fluid may include a base fluid; and a crosslinked and branched polymeric fluid loss control agent formed from at least an acrylamide monomer and a sulfonated anionic monomer; wherein the coiled tubing wellbore fluid has a low shear rate viscosity, measured at 120F at 3pm, of at least 20,000 centipoise.
A technique to facilitate removal of various types of particulates from fluids during well operations. The technique may employ a skid positioned at a surface location. A filtration system is mounted on the skid to enable filtration of particulates as the subject fluid flows from a system inlet to a system outlet. The filtration system comprises a bank of filtering stages arranged generally horizontally on the skid. For example, a first stage may be constructed with a generally horizontal vessel containing a first filter arranged to filter particulates from the fluid. The first stage also may comprise a magnet positioned to retain ferrous debris. Additionally, a second stage receives fluid exiting from the first stage and contains a second filter for further filtering of particulates from the fluid.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B01D 29/00 - Filters with filtering elements stationary during filtration, e.g. pressure or suction filters, not covered by groups Filtering elements therefor
B01D 36/02 - Combinations of filters of different kinds
Apparatus and vibratory separators having a base, a separator housing movably connected with the base, the separator housing including a top having an inlet chute, a bottom having a liquid discharge chute, a cylindrical sidewall defining an axial centerline and having a discharge spout, and at least one screen mounted within the separator housing. A vacuum system proximate the at least one screen may also be incorporated. The apparatus further includes at least one circular force generator (CFG) disposed on the separator housing, and at least one sensor positioned on the apparatus for measuring an operating function associated with and enabled by the vibration profile, and a controller in electronic communication with the sensor and with the at least one CFG. The difference between the measured operating function and the prescribed operating function is reduced. The apparatus may also include at least one CFG having a plurality of imbalanced masses which rotate in a plane parallel the axial centerline. The CFG may be disposed in an annular ring arrangement on the top, on the bottom, or CFGs disposed on both the top and the bottom.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B06B 1/16 - Processes or apparatus for generating mechanical vibrations of infrasonic, sonic or ultrasonic frequency making use of mechanical energy operating with systems involving rotary unbalanced masses
B07B 1/38 - Moving screens not otherwise provided for, e.g. swinging, reciprocating, rocking, tilting, or wobbling screens oscillating in a circular arc in their own planePlansifters
B07B 1/42 - Drive mechanisms, regulating or controlling devices, or balancing devices, specially adapted for screens
B06B 1/02 - Processes or apparatus for generating mechanical vibrations of infrasonic, sonic or ultrasonic frequency making use of electrical energy
H02K 7/06 - Means for converting reciprocating motion into rotary motion or vice versa
Vibratory separator screens separate solids and/or fluids, methods form said screens and vibratory screen apparatuses utilize said screens. The vibratory separator screens, methods and apparatuses have a mesh portion having a first side of the mesh portion and an opposite second side of the mesh portion, a first hem crimp affixed to the first side of the mesh portion, and a second hem crimp affixed to the second side of the mesh portion.
Vibratory separator screens separate solids and/or fluids, methods form said screens and vibratory screen apparatuses utilize said screens. The vibratory separator screens, methods and apparatuses have a mesh portion having a first side of the mesh portion and an opposite second side of the mesh portion, a first hem crimp affixed to the first side of the mesh portion, and a second hem crimp affixed to the second side of the mesh portion.
A wellbore fluid may include an oleaginous fluid forming a continuous phase; a non-oleaginous fluid forming a discontinuous phase; at least one emulsifier stabilizing an emulsion of the non-oleaginous continuous phase within the oleaginous continuous phase; and at least one viscosifier dispersed into the oleaginous continuous phase in a concentration of at least 4 ppb; wherein upon subjecting the wellbore fluid to shear rate of at least 10,000 s-1, the emulsion is disrupted and the non-oleaginous fluid contacts the at least one viscosifier, thereby solidifying the wellbore fluid.
C09K 8/514 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
E21B 33/138 - Plastering the borehole wallInjecting into the formation
Apparatus and methods for degassing and analyzing drilling fluid discharged from a wellbore at an oil and gas wellsite. The apparatus may be a drilling fluid analysis system having a gas analyzer, a fluid analyzer, and a degasser operable to release and separate mud gas entrained in the drilling fluid. The degasser may include a gas-liquid separator having a separator inlet configured to receive the drilling fluid containing the entrained mud gas, a first separator outlet for discharging the mud gas fluidly connected with the gas analyzer, and a second separator outlet for discharging degassed drilling fluid fluidly connected with the fluid analyzer.
22, where R is a fatty acid alkyl and R' is an alkyl group. The one or more additives are chosen from a wetting agent, a rheology modifier, a fluid-loss control additive, and a weighting additive. Methods of making the oil-based drilling fluid compositions and methods of drilling a subterranean well utilizing the oil-based drilling fluid compositions are also provided.
Embodiments for an oil-based drilling fluid and methods of making the oil-based drilling fluid are provided, in which the oil-base drilling fluid comprising: an oil phase; an aqueous phase; at least one surfactant, in which at least one surfactant comprises a carboxylic acid having 10 or more glycol repeating units; and optionally, at least one emulsifying agent.
The present application discloses drilling fluid compositions, methods for making drilling fluids, and methods for drilling subterranean wells utilizing the drilling fluids. According to one embodiment, a drilling fluid composition may include an oil phase, an aqueous phase, an emulsifier, and a rheology modifier. The emulsifier may include an amino amide, and the rheology modifier may include a layered double hydroxide, such as Mg/Al-Myristate layered double hydroxide.
The present application discloses drilling fluid compositions, methods for making drilling fluids, and methods for drilling subterranean wells utilizing the drilling fluids. According to one embodiment, a drilling fluid composition may include an oil phase, an aqueous phase, and a rheology modifier. The rheology modifier may include a layered double hydroxide, such as Mg/Al-Myristate layered double hydroxide.
A drilling fluid and a method of preparing the drilling fluid. The oil-based drilling fluid includes a base oil continuous phase comprising a base oil, an aqueous dispersed phase and at least one rheology modifier. The at least one rheology modifier includes a magnesium/aluminum (Mg/Al) layered-double hydroxide (LDH) diamondoid compound.
Described herein are splitters for holding and distributing input material to one or more decks of a gyratory sifter, where the splitter distributes approximately an equal amount of input material to each deck. An exemplary splitter may include a bottom surface, a sidewall, and one or more openings through the sidewall. Each opening may include a plurality of slits, allowing input material to pass therethrough. Where multiple openings are provided through the sidewall, the openings may be evenly spaced and have an equivalent area. The bottom surface may be substantially circular, and the sidewall may extend perpendicularly from the edges of the bottom surface. An exemplary splitter may be able to receive and distribute the input material when a gyratory force acts on the gyratory sifter on which the splitter is installed.
B07B 1/38 - Moving screens not otherwise provided for, e.g. swinging, reciprocating, rocking, tilting, or wobbling screens oscillating in a circular arc in their own planePlansifters
56.
OIL-BASED DRILLING FLUIDS FOR HIGH PRESSURE AND HIGH TEMPERATURE DRILLING OPERATIONS
22, where R is a fatty acid alkyl and R' and R" are alkyl groups. The one or more additives are chosen from a wetting agent, a rheology modifier, a fluid-loss control additive, and a weighting additive. Methods of making the oil-based drilling fluid compositions and methods of drilling a subterranean well utilizing the oil-based drilling fluid compositions are also provided.
An apparatus includes a first fines pan side traversing from a feed end to a discharge end, a second fines pan side traversing from the feed end to the discharge end opposite the first fines side, a first surface traversing from the first fines pan side upwards towards an apex of the fines pan, and a second surface traversing from the second fines pan side upwards towards the apex of the fines pan, the first fines pan side, the second fines pan side, the first surface, and the second surface forming a fines pan. The first fines side having a first fines opening proximate the discharge end. The second fines side having a second fines opening proximate the discharge end.
Methods may include quantifying the concentration of residual free amine and/or free carboxylic acid in a product mixture prepared from a reaction of a multireactive species and a fatty reagent; verifying that the concentration for the free amine and/or free acid in the product mixture is within an acceptable threshold for a given application; and combining the product mixture with one or more wellbore fluid components to generate the wellbore fluid. In another aspect, methods may include including reacting the multireactive species and a fatty reactant to generate a product mixture; quantifying the concentration of residual free amine and/or free carboxylic acid in the product mixture; verifying that the concentration for the free amine and/or free acid in the product mixture is within an acceptable threshold for a given application; and collecting the product mixture.
C07C 231/02 - Preparation of carboxylic acid amides from carboxylic acids or from esters, anhydrides, or halides thereof by reaction with ammonia or amines
A system includes a fluid conduit, a fluid chamber in communication with the fluid conduit, a rheology sensor in communication with the fluid chamber, and an electric temperature controller in communication with the fluid chamber. The fluid chamber is cooled in response to a first control signal from the electric temperature controller.
G01N 25/16 - Investigating or analysing materials by the use of thermal means by investigating thermal coefficient of expansion
G01N 9/36 - Analysing materials by measuring the density or specific gravity, e.g. determining quantity of moisture
E21B 47/103 - Locating fluid leaks, intrusions or movements using thermal measurements
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
An apparatus includes an outer bearing member defining a cavity and an inner bearing member disposed within the cavity. The inner bearing member includes a spherical surface and a rod attachment opening defined in the spherical surface. The apparatus also includes an elastomeric material disposed within the cavity adjacent to the spherical surface.
A method of treating petroleum fluids includes adding a wax inhibitor composition to the petroleum fluids, the wax inhibitor composition, including a wax inhibitor; a non-ionic surfactant or a cationic surfactant; and a co-solvent blend. A method of treating a petroleum fluid, includes adding a wax inhibitor composition to the petroleum fluid, the wax inhibitor composition including a wax inhibitor; an anionic surfactant selected from at least one of an isopropylamine dodecylsulfonic acid salt or an isopropylamine linear dodecylbenzene sulfonate; and a co-solvent blend.
C10G 75/04 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of antifouling agents
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
A system for separating components from a slurry of drilling fluid and drill cuttings on a shaker screen having an upper side and a lower side within a shaker. The system also has a pressure differential generator to pull an effective volume of air through a section of the shaker screen to enhance the flow of drilling fluid through the section of the shaker screen and the separation of drilling fluid from drill cuttings and further maintain an effective flow of drill cuttings off the shaker. A method of separating components of a slurry of drilling fluids and solids has the steps of delivering the slurry to a shaker, flowing the slurry over a first screen and applying an effective amount of vacuum to a first portion of the first screen to remove the drilling fluids from the slurry without stalling the solids on the first screen.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B07B 1/46 - Constructional details of screens in generalCleaning or heating of screens
B01D 33/03 - Filters with filtering elements which move during the filtering operation with translationally moving filtering elements, e.g. pistons with vibrating filter elements
B01D 33/72 - Filters with filtering elements which move during the filtering operation having feed or discharge devices for feeding
A device and system applicable to separating components of a slurry is disclosed. The slurry can be a mixture of drilling fluid and drilling cuttings that can be separated with a separatory screen. A separatory tray can be disposed below an underside of the separatory screen. A pressure differential pan can provide fluid flow to a sump. A pressure differential generator can be located within the pressure differential pan and create a pressure differential between an upper side and a lower side of the separatory screen to enhance the flow of drilling fluid through the separatory screen.
B07B 4/08 - Separating solids from solids by subjecting their mixture to gas currents while the mixtures are supported by sieves, screens, or like mechanical elements
B03B 4/02 - Separating by pneumatic tables or by pneumatic jigs using swinging or shaking tables
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B07B 4/00 - Separating solids from solids by subjecting their mixture to gas currents
B07B 1/28 - Moving screens not otherwise provided for, e.g. swinging, reciprocating, rocking, tilting, or wobbling screens
B07B 1/42 - Drive mechanisms, regulating or controlling devices, or balancing devices, specially adapted for screens
A fluid loss control agent may include at least one thinner; and at least one polymeric component. A wellbore fluid may include a base fluid and a fluid loss control agent, which includes at least one thinner and at least one polymeric component. Methods of use are also described.
An apparatus includes a manifold plate-like structure having two end regions and an opening located in the recessed region configured to allow fluid flow therethrough and a clamping device. The clamping device includes a first clamping block and a first mechanical fastener to couple the first clamping block and the manifold. The apparatus also includes a vibratory separator including a basket having support structure therein, the manifold coupled to the support structure with a clamping device. A pan is disposed above the manifold and coupled to the manifold and a screen is disposed on the pan. A pressure differential device is coupled to the manifold and configured to provide a pressure differential across the screen. A method includes coupling the manifold to the support structure, disposing the pan on the support structure, and coupling the pan to the manifold.
A system, an apparatus and a method for adjusting a weir control the rate and/or speed at which drilling fluid feeds a separator. Multiple separators are typically used in parallel to process fluid returning from the well. A distribution manifold directs fluid to each separator. The weir is positioned within a feeder on an inlet end of the separator and connects to an attachment plate within the feeder. The distribution manifold or other flow control mechanism operates in combination with the weir. Adjustment apparatuses control the height of the weir to determine the rate the fluid flows onto the separator. The adjustment apparatuses provide mechanical and/or automated operation of the weir. Various profiles of the weir and adjustments of the height of the weir within the feeder increase and/or decrease the speed of the fluid as the fluid spills into the separator.
A method of drilling a wellbore includes pumping an oleaginous wellbore fluid into a wellbore, the oleaginous wellbore fluid including an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase; an organophilic clay; a weighting agent; and a wetting agent having an HLB ranging from about 4 to 10.5 that it selected such that the oleaginous wellbore fluid has a 600 rpm dial value at 40 °F of less than about 300 and a 10 minute gel strength of less than about 40 lbf/100ft2.
An additive composition includes a rheology modifier selected from alcohol ethoxylates, amine ethoxylates, or ethylene oxide/propylene oxide copolymers, wherein the rheology modifier has an HLB ranging from about 4 to 10; and a winterizing agent that is at least one aliphatic non-ionic surfactant that has a branched structure and/or includes at least one unsaturation, wherein the winterizing agent has an HLB value between about 8 and 10.5.
An apparatus includes a materials separator that includes a continuous filter belt disposed around a plurality of rollers. The apparatus also includes a pressure differential system operatively coupled to the separator and configured to adjust a pressure differential across the continuous filter belt. A vacuum is applied to the continuous filter belt and a fluid portion of the slurry on the continuous filter belt is drawn through the continuous filter belt. An apparatus includes a materials separator having a first deck with a first continuous filter belt and a second deck with a second continuous filter belt.
B01D 33/048 - Filters with filtering elements which move during the filtering operation with filtering bands or the like supported on cylinders which are pervious for filtering with endless filtering bands
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
71.
System and method for recycling liquid separated from wellbore cuttings
Systems and methods recycle liquid(s) by introducing at least a portion of a first liquid from a first centrifuge into a tank. At least a portion of a second liquid is introduced from a second centrifuge into the tank. The first liquid and the second liquid are mixed together in the tank to produce a mixed liquid. At least a portion of the mixed liquid is introduced from the tank into the second centrifuge. Particles from the mixed liquid are separated using the second centrifuge, thereby producing the at least a portion of the second liquid that is introduced from the second centrifuge into the tank.
A breaker fluid includes a base fluid; lactide; and a mixture of hydrolyzable esters of dicarboxylic acids. A method of breaking a filtercake in a wellbore includes circulating a breaker fluid into the wellbore, the breaker fluid including: a base fluid; lactide; and a mixture of hydrolyzable esters of dicarboxylic acids.
Compositions may include those of the formula: (I) wherein R1 is an alkyl chain having a carbon number in the range of greater than 40 to 200, R2 is a multiester, R3 is hydrogen, an ion, or an alkyl chain having a carbon number in the range of 1 to 200, m is an integer selected from 0 to 4, and n is an integer selected from the range of 0 to 4, wherein the sum of m and n is 1 or greater. Compositions may include a reaction product of a polyisobutylene-substituted succinic anhydride and a hydroxy- functional dendrimer, wherein the molar ratio of polyisobutylene-substituted succinic anhydride to hydroxy-functional dendrimer is within the range of 10: 1 to 30: 1.
Methods may include emplacing into a hydrocarbon production stream a composition containing an asphaltene inhibitor, wherein the asphaltene inhibitor includes the formula (I) wherein R1 is an alkyl chain having a carbon number in the range of greater than 40 to 200, R2 is a multiester group, R3 is hydrogen, an ion, or an alkyl chain having a carbon number in the range of 1 to 200, m is an integer selected from 0 to 4, and n is an integer selected from the range of 0 to 4, wherein the sum of m and n is 1 or greater. Methods may also include emplacing in a wellbore a composition containing an asphaltene inhibitor, wherein the asphaltene inhibitor comprises esters of the formula (I) wherein R1 is an alkyl chain having a carbon number in the range of greater than 40 to 200; R2 is a multiester group; is hydrogen, an ion, or an alkyl chain having a carbon number in the range of 1 to 200; m is an integer selected from 0 to 4; and n is an integer selected from the range of 0 to 4, wherein the sum of m and n is 1 or greater.
A composition comprising an oleaginous base fluid, an emulsifier and a liquid tertiary amide is disclosed. A wellbore fluid may include an oleaginous continuous phase, a non-oleaginous discontinuous phase and the composition to stabilize the non-oleaginous discontinuous phase within the oleaginous continuous phase. A method comprising adding the composition to a wellbore fluid and emplacing the wellbore fluid mixed with the composition into a wellbore is also provided.
An example modeling process of pore pressure and injected waste distribution profile may include several steps. A hydrodynamic flow simulation model may be built according to the geometry and/or physical properties of the subsurface formation. A fluid distribution and pore pressure profile in the subsurface may be affected by the geometry and orientation of hydraulic fractures created as a result of drill cuttings subsurface injection (cuttings re-injection or CRI). A fracture profile may be generated using a hydraulic fracturing simulation and may then be embedded into the hydrodynamic simulation model. In some examples, the nature of injected fluids in the same formation and through the same well, fracture, and/or perforation interval may lead to modification of the subsurface formation properties, and this may be accounted for in the simulation.
G06F 30/20 - Design optimisation, verification or simulation
E21B 41/00 - Equipment or details not covered by groups
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
The present disclosure relates to methods of controlling a microbial level in an aqueous fluid or a solid component used in an oilfield operation or a pre- or post-production process associated with wellbore production, the method comprising: measuring a microbial parameter of the aqueous fluid; and subsequently using the measured microbial parameter to decide on an appropriate antimicrobial treatment. These proposals also relate to methods further including monitoring of a microbial parameter in such a fluid or on such a solid component over a period of time. The methods and aspects of the present disclosure may be applied in any oilfield operation or a pre- or post-production process associated with wellbore production.
A01N 35/02 - Biocides, pest repellants or attractants, or plant growth regulators containing organic compounds containing a carbon atom having two bonds to hetero atoms with at the most one bond to halogen, e.g. aldehyde radical containing aliphatically bound aldehyde or keto groups, or thio-analogues thereofDerivatives thereof, e.g. acetals
A01N 43/88 - Biocides, pest repellants or attractants, or plant growth regulators containing heterocyclic compounds having rings with nitrogen atoms and oxygen or sulfur atoms, as ring hetero atoms six-membered rings with three ring hetero atoms
A01N 57/20 - Biocides, pest repellants or attractants, or plant growth regulators containing organic phosphorus compounds having phosphorus-to-carbon bonds containing acyclic or cycloaliphatic radicals
A01N 59/08 - Alkali metal chloridesAlkaline earth metal chlorides
C09K 8/84 - Compositions based on water or polar solvents
A system including a vibratory separator includes at least one screen and a pressure differential system. The pressure differential system includes a pressure differential generating device, a tray coupled to the pressure differential generating device, and an adjustable mounting mechanism configured to couple the tray within the vibratory separator and adjust a distance between the tray and the at least one screen of the vibratory separator.
F26B 9/08 - Machines or apparatus for drying solid materials or objects at rest or with only local agitationDomestic airing cupboards in stationary drums or chambers including agitating devices
A centrifugal dryer includes a housing and a basket positioned within the housing. The basket defines an opening formed laterally there through. The basket rotates around a central longitudinal axis through the housing. An annulus is formed between the basket and the housing. A cleaning device is positioned within the annulus, and the cleaning device introduces a liquid into the annulus. A scraping device is positioned within the annulus, and the scraping device rotates to remove cuttings from at least one surface.
B04B 3/04 - Centrifuges with rotary bowls in which solid particles or bodies become separated by centrifugal force and simultaneously sifting or filtering discharging solid particles from the bowl by a conveying screw co-axial with the bowl axis and rotating relatively to the bowl
This disclosure is generally drawn to systems, devices, apparatuses, and/or methods, related to monitoring a shaker and monitoring a room in which shaker(s) operate. Specifically, the disclosed systems, devices, apparatuses, and/or methods relate to controlling an actuated arm to inspect, remove, replace, repair, clean the shaker and/or screen assemblies based on monitoring the shaker and its screen assemblies, and to adjust or maintain shaker(s) in a defined area such as the room in which shaker(s) operate. While the examples disclosed herein generally describe shakers for separating solids from fluids, the present disclosure contemplates that other separation equipment (e.g., machines for separating solids from other solids) may also be monitored and controlled by the systems and methods described herein.
Compositions may include a wax modifier that is the product of a reaction between a polysaccharide having a number of sugar subunits in the range of 2 to 60 and one or more fatty acid reagents, and a reservoir fluid produced from a subterranean formation comprising one or more components capable of producing waxes. Methods may include contacting a hydrocarbon fluid with a wax modifier, wherein the wax modifier is the product of the reaction of a polysaccharide and one or more fatty acid reagents. Methods may also include introducing a wax modifier into a wellbore penetrating a subterranean formation, wherein the wax modifier is the product of a reaction between a polysaccharide and one or more fatty acid reagents; producing hydrocarbons from the subterranean formation; and allowing the wax modifier to inhibit the precipitation of a wax.
Wellbore fluids may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; and an emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the emulsifier is the product of a reaction between an alkyl cyclic anhydride and a polar reactant, wherein the polar reactant is one or more selected from a group containing alkyl amine, alkanolamine, and polyamine. Methods may include drilling a wellbore with an oil-based mud, wherein the oil-based mud is an invert emulsion containing an emulsifier stabilizing the invert emulsion, wherein the emulsifier is the product of a reaction between an alkyl cyclic anhydride and a polar reactant, wherein the polar reactant is one or more selected from the group of alkyl amine, alkanolamine, and polyamine.
Compositions may include a wax modifier that is the product of a reaction between a polysaccharide having a number of sugar subunits in the range of 2 to 60 and one or more fatty acid reagents, and a reservoir fluid produced from a subterranean formation comprising one or more components capable of producing waxes. Methods may include contacting a hydrocarbon fluid with a wax modifier, wherein the wax modifier is the product of the reaction of a polysaccharide and one or more fatty acid reagents. Methods may also include introducing a wax modifier into a wellbore penetrating a subterranean formation, wherein the wax modifier is the product of a reaction between a polysaccharide and one or more fatty acid reagents; producing hydrocarbons from the subterranean formation; and allowing the wax modifier to inhibit the precipitation of a wax.
C09K 8/03 - Specific additives for general use in well-drilling compositions
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
F17D 3/12 - Arrangements for supervising or controlling working operations for injecting a composition into the line
C10G 75/04 - Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general by addition of antifouling agents
C11C 1/00 - Preparation of fatty acids from fats, fatty oils, or waxesRefining the fatty acids
A wellbore fluid, comprising an oleaginous continuous phase, a non-oleaginous discontinuous phase and a polymer having a polycyclic backbone. A method of drilling comprising pumping the said wellbore fluid into a wellbore through an earthen formation is also described.
A valve assembly (1) for use particularly in a deviated wellbore of an oil, gas or water well comprises a body (50) with an axis and first and second resiliently deformable seats (20, 25) to seat a valve closure member (10a) such as a ball, the seats being deformable to allow passage of the ball at different first and second fluid pressures acting on the seated valve closure member. The first and second seats are axially spaced from one another on a control sleeve (60) on opposite sides of an inner end of a selectively operable fluid outlet conduit connecting the bore with an external surface of the valve assembly, and operation of the valve assembly at pressures between the first and second pressures opens and closes the outlet while maintaining the ball between the first and second seats.
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
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 filter device housed within a body component. The filter device can include an outer filter and an inner filter positioned coaxially within the outer filter. The outer and inner filters may be composed of a material having mesh, slots, holes, or any other openings being of a sufficient size and shape to restrict passage of items of a predetermined size or larger. Formed between the inner and outer filters is a first annular space into which fluid that is provided down the drill string may enter. The filter device may also include a valve within the internal bore which regulates passage of wellbore fluid provided to the drill string, or for a wireline or slickline, to pass through the filter device in order to access other components of the drill string downhole from the filter device.
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 37/00 - Methods or apparatus for cleaning boreholes or wells
This disclosure is drawn systems, devices, apparatus, and/or methods related to the separation of a mixture of solids according to size and the separation of solids from liquid. Specifically, this disclosure is drawn to an adjustable weight set for use on vibratory separators. In some examples, the adjustable weight set may include a base plate rotatable about an axis and extending radially outward from the axis; a plurality of slots extending through the base plate and being disposed between a radially outward periphery of the base plate and the axis; a plurality of weights coupled to each other about the base plate; and a weight locking tab that partially surrounds the base plate that may include one or more hooks extending through a portion of a slot.
Systems and methods for generating a pressure differential below a screen in a vibratory separator to urge a substance being separated to pass through the screen of the vibratory separator are disclosed. Pressurized fluid is supplied to a pressure differential generator to generate a pressure differential across a screen of the vibratory separator. A securement assembly secures a tray to the vibratory separator. The tray has a drain separate from a pressure differential generator. An interior of the drain and an interior passage of the pressure differential generator can connect at a location in which pressurized fluid entering the pressure differential generator does not cause detrimental effects to the substance being separated.
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Oil and gas well treatment; Mixing lubricants for third parties, namely, mixing of well bore drilling fluids for use by others; preparation and treatment of well bore drilling fluids for use by others; Technical consulting in the field of oil and gas production and processing; Consulting services, namely, consultation regarding the selection of well bore drilling fluids for others suitable for intended use Providing technology information relating to oil and gas industry; Technological consulting in relation to technical research in the field of well bore drilling fluids; Technical analysis services for oil field exploration, namely, the custom design and development of well bore drilling fluids for others; Technical analysis services for oil field exploration for scientific research purposes, namely, the monitoring of well bore drilling fluids for others for quality control purposes; Technological consultation in the field of petroleum exploration, namely, the design of well bore drilling fluids for others; Technology consultation in the field of petroleum exploration in the nature of selecting well bore drilling fluids for others suitable for intended use; Technology consultation in the field of petroleum exploration, namely, the monitoring of well bore drilling fluids for others for quality control purposes; consulting services in the field of environmental assessment and planning, namely, performing oil well assessment for others
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Oil and gas well treatment; Mixing lubricants for third parties, namely, mixing of well bore drilling fluids for use by others; Preparation and treatment of well bore drilling fluids for use by others; Technical consulting in the field of oil and gas production and processing; Consulting services, namely, consultation regarding the selection and treatment of well bore drilling fluids for others suitable for intended use Providing technology information relating to oil and gas industry; Technological consulting in relation to technical research in the field of well bore drilling fluids; Technical analysis services for oil field exploration, namely, the custom design and development of well bore drilling fluids for others; Technical analysis services for oil field exploration for scientific research purposes, namely, the monitoring of well bore drilling fluids for others for quality control purposes; Technological consultation in the field of petroleum exploration, namely, the design of well bore drilling fluids for others; Technology consultation in the field of petroleum exploration in the nature of selecting well bore drilling fluids for others suitable for intended use; Technology consultation in the field of petroleum exploration, namely, the monitoring of well bore drilling fluids for others for quality control purposes; Consulting services in the field of environmental assessment and planning, namely, performing oil well assessment for others
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Oil and gas well treatment; Mixing lubricants for third parties, namely, mixing of well bore drilling fluids for use by others; Preparation and treatment of well bore drilling fluids for use by others; Technical consulting in the field of oil and gas production and processing; Consulting services, namely, consultation regarding the selection and treatment of well bore drilling fluids for others suitable for intended use Providing technology information relating to oil and gas industry; Technological consulting in relation to technical research in the field of well bore drilling fluids; Technical analysis services for oil field exploration, namely, the custom design and development of well bore drilling fluids for others; Technical analysis services for oil field exploration for scientific research purposes, namely, the monitoring of well bore drilling fluids for others for quality control purposes; Technological consultation in the field of petroleum exploration, namely, the design of well bore drilling fluids for others; Technology consultation in the field of petroleum exploration in the nature of selecting well bore drilling fluids for others suitable for intended use; Technology consultation in the field of petroleum exploration, namely, the monitoring of well bore drilling fluids for others for quality control purposes; Consulting services in the field of environmental assessment and planning, namely, performing oil well assessment for others
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
Oil and gas well treatment; Mixing lubricants for third parties, namely, mixing of well bore drilling fluids for use by others; preparation and treatment of well bore drilling fluids for use by others; Technical consulting in the field of oil and gas production and processing; Consulting services, namely, consultation regarding the selection of well bore drilling fluids for others suitable for intended use Providing technology information relating to oil and gas industry; Technological consulting in relation to technical research in the field of well bore drilling fluids; Technical analysis services for oil field exploration, namely, the custom design and development of well bore drilling fluids for others; Technical analysis services for oil field exploration for scientific research purposes, namely, the monitoring of well bore drilling fluids for others for quality control purposes; Technological consultation in the field of petroleum exploration, namely, the design of well bore drilling fluids for others; Technology consultation in the field of petroleum exploration in the nature of selecting well bore drilling fluids for others suitable for intended use; Technology consultation in the field of petroleum exploration, namely, the monitoring of well bore drilling fluids for others for quality control purposes; consulting services in the field of environmental assessment and planning, namely, performing oil well assessment for others
93.
Optimization of drilling assembly rate of penetration
In drilling into a subterranean formation, several factors influence the rate of penetration, including, but not limited to, the type of formation being drilled, the weight on bit, and the rotational speed of the drill bit. Disclosed are a system and method for controlling the rotational speed of a drill bit based on regulation of fluid flow to the motor driving the bit, while maintaining at least a minimum flow of fluid to the annulus to clear debris from downhole during drilling. Regulation of fluid flow to the motor and to the annulus may be accomplished utilizing a flow diverter configured to adjust a flow ratio depending on drilling conditions in order to maximize efficiency of the motor downhole during drilling.
A method of reducing fluid loss includes pumping a wellbore fluid including resin coated solid particulate into a wellbore having fractures therein, the resin coated solid particulate forming a substantially impermeable plug in the fractures. A method of drilling a wellbore includes drilling a wellbore through a formation using a first wellbore fluid; and upon experiencing a fluid loss event to the formation, pumping a second wellbore fluid including resin coated solid particulates into the wellbore.
Systems and methods for directing a pressure differential below a screen in a shale shaker to urge fluid to pass through the shaker. A support unit including a tray and a movable arm supports a pressure differential generating device. The support unit can be positioned relative to the shale shaker with the tray in position to collect fluid passing through a screen of the shale shaker. The pressure differential generating device generates a pressure differential that pulls fluid through the screen. One or more slot trays are positioned between the pressure differential generating device, the screen, and some supporting structure of the frame of the shaker. The slot trays distribute the pressure differential around the screen.
A scalping insert includes a scalping surface having a plurality of scalping slots therethrough, and a vertical base portion. A shaker screen assembly includes a screen frame having at least one slot. A scalping insert is positioned in the at least one slot of the screen frame. Processing fluid using a shaker screen assembly includes providing a flow of fluid to the shaker screen assembly and flowing the fluid through both a scalping surface and a screen surface of a single shaker screen deck.
A composition may comprise a solvent and at least a sulphosuccinate. Methods may include injecting a flow improver composition into a diluent supply line; contacting a crude oil product with the flow improver composition mixed with the diluent to form a diluted crude oil; and processing the diluted crude oil to form a processed crude oil. Methods may also include injecting a flow improver composition into a crude oil product with the formation of a treated crude oil and processing the treated crude oil to form a processed crude oil.
C10G 21/02 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents with two or more solvents, which are introduced or withdrawn separately
Disclosed herein is an agglomeration-resistant desulfurizing product for removing contaminants from a fluid stream. The agglomeration-resistant desulfurizing product comprising a metal oxide composition for reacting with contaminants and a polymeric crystallization inhibitor for reducing the agglomeration of the desulfurizing product resulting from using the desulfurizing product. A method to produce the agglomeration-resistant desulfurizing product and a method to treat a fluid stream is also disclosed.
B01J 20/00 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof
B01D 53/00 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols
C10G 70/00 - Working-up undefined normally gaseous mixtures obtained by processes covered by groups , , , ,
C10L 3/10 - Working-up natural gas or synthetic natural gas
B32B 15/04 - Layered products essentially comprising metal comprising metal as the main or only constituent of a layer, next to another layer of a specific substance
B32B 15/10 - Layered products essentially comprising metal comprising metal as the main or only constituent of a layer, next to another layer of a specific substance of wood
An apparatus includes a first fines pan side traversing from a feed end to a discharge end, a second fines pan side traversing from the feed end to the discharge end opposite the first fines side, a first surface traversing from the first fines pan side upwards towards an apex of the fines pan, and a second surface traversing from the second fines pan side upwards towards the apex of the fines pan, the first fines pan side, the second fines pan side, the first surface, and the second surface forming a fines pan. The first fines side having a first fines opening proximate the discharge end. The second fines side having a second fines opening proximate the discharge end.
B07B 1/28 - Moving screens not otherwise provided for, e.g. swinging, reciprocating, rocking, tilting, or wobbling screens
B07B 1/42 - Drive mechanisms, regulating or controlling devices, or balancing devices, specially adapted for screens
B07B 13/04 - Grading or sorting solid materials by dry methods, not otherwise provided forSorting articles otherwise than by indirectly controlled devices according to size
An apparatus, system and method for fastening a screen has a screen with apertures sized to separate a first sized material from a second sized material. A box is positioned beneath the screen in a bracket extending along the screen. A protrusion extends from the box toward the screen. A triangular tensioning element secured along a length of the screen moves in a direction substantially perpendicular to the length of the screen in response to contact with the protrusion to seal the screen against the bracket and tension the screen.
B07B 1/46 - Constructional details of screens in generalCleaning or heating of screens
B07B 13/04 - Grading or sorting solid materials by dry methods, not otherwise provided forSorting articles otherwise than by indirectly controlled devices according to size
