Abstract: A method includes admixing an aqueous polysaccharide solution into an oleaginous base fluid, and adding a divalent ion source to produce one or more polysaccharide microspheres.

Abstract: As disclosed herein, an oil-based fluid includes an oleaginous continuous phase, a non-oleaginous discontinuous phase, and a plurality of psyllium seed husks.

Abstract: The present invention provides a method of isolating a selected reservoir zone in a subterranean reservoir comprising at least the step of squeezing a treatment fluid into the selected reservoir zone, the treatment fluid comprising: a viscosifying agent; a fluid loss control agent; and a particulate material. The invention further provides a treatment fluid comprising a base fluid; a viscosifying agent; at least 20 kg/m3 of a fluid loss control agent; and a particulate material.

Abstract: A wellbore strengthening composition may include a base fluid and at least one polymer functionalized with electrochemically activated groups. A method of treating a wellbore may include emplacing, in at least a selected region of the wellbore, a wellbore strengthening composition including a base fluid and at least one polymer functionalized with electrochemically activated groups. The method may also include emplacing a downhole tool capable of generating a voltage potential in the wellbore and applying a voltage potential in the wellbore with the downhole tool.

Abstract: Wellbore strengthening compositions may include a base fluid; and a solid gum rosin additive, wherein the solid gum rosin additive has an average particle size of 1 ?m to 15 mm. Methods may include emplacing a wellbore fluid containing a solid gum rosin additive into a wellbore wherein the solid gum rosin additive has an average particle size of 1 ?m to 15 mm.

Abstract: Accretion inhibiting wellbore fluid compositions a ay contain a multiester, a sorbitan ester surfactant, and a base fluid, wherein the composition is in the form of a metastable emulsion. Methods may include emplacing a wellbore fluid into a wellbore, the wellbore fluid containing a multiester, and a sorbitan ester surfactant, wherein the wellbore fluid forms a metastable emulsion.

Abstract: A well fluid test device includes a cell body having a first end port disposed on an upper end of the cell body, a second end port disposed on a lower end of the cell body, a first lateral port disposed on a side of the cell body, and a second lateral port disposed on a side of the cell body, and a filter medium disposed in the cell body, wherein the first and second lateral ports are disposed above the filter medium. A method of evaluating a fluid includes injecting a fluid into a well fluid test device, the well fluid test device having a filter medium, heating the fluid in the well fluid test device, establishing a pressure differential across the filter medium, establishing a filter cake on the filter medium, and maintaining at least one of a temperature and a pressure in the well fluid test device.

Abstract: A method for cleaning a reactor, the method including circulating a fluid inside the reactor, pumping the fluid from the reactor into an inlet of a tank cleaner, and removing solids from the fluid to produce a clean fluid. The method further includes transferring the clean fluid to the reactor and transferring pneumatically the removed solids to a pressurized vessel. Also, a method for transferring spent granular material, the method including providing a vacuum system disposed at a hydrocarbon production site to remove spent material from a reactor, transferring the spent material through the vacuum system into a pressurized vessel, and conveying pneumatically the spent material from the pressurized vessel to a second pressurized vessel.

Abstract: A method of optimizing a hydrogen sulfide scavenger blend that includes selecting a hydrogen sulfide scavenger blend comprising at least two hydrogen sulfide scavengers; determining a scavenging capacity for the blend; modifying at least one blend parameter based on the determined scavenging capacity; redetermining the scavenging capacity for the modified blend; and selecting an optimized blend from the blend and the modified blend is disclosed.

Abstract: A flotation unit for purifying water, comprising at least a separator tank, a supply duct to a tank inlet, outlets for gas, oil and water from the tank, and a gas injector located in the supply duct, said gas injector comprising a venturi section having an inner diameter and a cross-sectional area smaller than a cross-sectional area of the supply duct, an ejector arranged in the venturi section and having an outer side facing an inside surface of the venturi section, an inner side facing a longitudinal center axis of the venturi section, a downstream side, and a upstream side, the ejector comprising an annular gas distribution chamber and a plurality of gas outlets arranged along a side of the ejector and connected to the gas distribution chamber, and a gas inlet for supplying gas to the gas distribution chamber, wherein the ejector has an outer diameter which is smaller than the inner diameter of the venturi section.

Abstract: An automatic drilling fluid property analyzer including a housing having an inlet and an outlet; at least one valve disposed proximate the inlet and configured to open and close to provide a sample of fluid into the housing; an electronic control module configured to send a signal to the at least one valve; a probe assembly operatively coupled to the electronic control module, the probe assembly including an electrode probe having two electrodes and a probe gap therebetween; a viscometer sleeve disposed in the housing; a bob disposed in the sleeve, wherein an annulus is formed between the viscometer sleeve and the bob, and wherein at least one of the viscometer sleeve and the bob is configured to rotate, a motor operatively coupled to at least one of the viscometer sleeve and the bob; and a torque measuring device operatively coupled to the viscometer sleeve and the bob.

Abstract: A system for mixing fluids for oilfield applications, the system including a first storage vessel (101) configured to hold a first material and a first mixing device (108) in fluid communication with the first storage vessel. The system also including a second mixing device (115) in fluid communication with the first mixing device and a second storage vessel (102) in fluid communication with the second mixing device, wherein the second storage vessel is configured to hold a second material. Additionally, the system including a pump (109) in fluid communication with at least the second storage vessel and the first mixing device, wherein the pump is configured to provide a flow of the second material from the second storage vessel to the first mixing device, and wherein the first mixing device is configured to mix the first material and the second material to produce a wellbore fluid.

Abstract: A method of transferring proppant materials, wherein the method includes providing a first pressurized container (102) containing proppant materials on a first vessel (106). The method also includes connecting the first pressurized container (102) on the first vessel (106) to a second container (102) on a second vessel (114) and transferring pneumatically, proppant materials from the first pressurized container (102) on the first vessel (106) to the second container (102) on the second vessel (114). Also, a method of transferring proppant materials, the method including removing a wellbore fluid comprising excess proppant materials from a well, and screening the excess proppant materials from the wellbore fluid. The method also includes transferring the excess proppant materials to a first pressurized container (102) and transferring pneumatically, the excess proppant materials from the first pressurized container to a second pressurized container.

Abstract: A number of variations may include a product including a fluid additive including at least one asphaltene dispersant/inhibitor including a branched dendritic core and at least one carboxylic acid moiety.

Abstract: A method includes determining particle size distribution (PSD) in a fluid flow line based on a range of sizes for at least one particle in the fluid flow line and duration of reflection of a laser beam from the at least one particle. The laser beam is focused from a laser beam instrument in direct contact with the fluid low line.

Abstract: A method of drilling is disclosed and includes pumping a wellbore fluid into a wellbore through an earth formation, wherein the wellbore fluid comprises a base fluid and a surface active agent capable of altering wettability of fines located in the earth formation, and allowing filtration of at least a portion of the wellbore fluid into the earth formation.

Abstract: A separator tank (1) for separating oil and gas from water comprises an essentially cylindrical vertical tank with at least one separator tank unit. The separator tank unit has an inlet for fluid (2) and a first inner annular wall (5) a first conical portion (9) and a first central opening (8). A second inner annular wall (15) is positioned at a distance from the first inner annular wall and has a second conical portion (19) and a second central opening (18). A first flow opening (10) is provided at an end of said first inner annular wall (5) and a second flow opening (20) is provided at an end of second inner annular wall (15).

Abstract: Disclosed herein is a fluid flow improver comprising a branched dendritic core comprising a first quaternary carbon center bonded to four second carbon atoms, wherein 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, and wherein at least one of the terminal hydroxyl groups is esterified with at least one carboxylic acid moiety comprising from 6 to 30 carbon atoms. Methods of inhibiting deposition of paraffin and reducing pour point temperature of a hydrocarbon fluid are also disclosed.

Abstract: A separator tank (1) for separating oil and gas from water, and comprising an essentially cylindrical vertical tank casing (3) with a plurality of separator tank units (2). The separator tank units (2, 2?, 2?) are arranged on top of one another within a central area in an inner annular enclosure (4) that divides the separator tank into an annular outer area (5) and the central area. The flow paths of fluids to inlets (7) in the separator tank units (2) and from at least one second outlet (9) in the separator tank units are arranged at least in the annular outer area.

Abstract: A separator tank (1) for separating oil and gas from water, and comprising separator tank units (2, 2?, 2?) arranged on top of one another within an annular enclosure (4). An inlet pipe (14) is connected with the inlet for fluid in a first of the at least two separator tank units. A second outlet (9) in the first separator tank unit (2) is connected with the inlet (7) for fluid in a second of the at least two separator tank units (2?). A pressure control device controls the pressure downstream of the first outlets for oil and gas (8) so that the pressure at the first outlets (8) is lower than the pressure at the water outlet (26) on the separator tank.