Abstract: A water treatment system includes an inlet line, a tank in fluid communication with the inlet line to receive therefrom a fluid flow comprising hydrocarbons and water. The tank includes components configured to separate the fluid flow into a hydrocarbon flow and a water flow, with the water flow including a residual amount of hydrocarbons. A first outlet line is in fluid communication with the tank to discharge therefrom the water flow. A second outlet line is in fluid communication with the tank to discharge therefrom the hydrocarbon flow. A sensor is associated with one of the inlet line, the first outlet line, and the second outlet line, and a valve is associated with the second outlet line. In addition, a controller is configured to determine a property of at least one of the fluid flow, the hydrocarbon flow, and the water flow using the sensor, and to control the valve based upon the property so as to reduce the residual amount of hydrocarbons in the water flow.

Abstract: An assembly includes at least one container, an injection medium supply, at least one flow line extending from the injection medium supply to an interior portion of the at least one container; and a pressure transducer coupled to each of the at least one flow line.

Abstract: A wellbore fluid comprising an aqueous base fluid and a plurality of particles of a polyhydroxyalkanoate latex polymer having the formula: [—O—CHR—(CH2)m—CO—]n, wherein m is a value ranging from 1 to 10 and n is a value equal to or less than 20000.

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 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: 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: Methods may include emplacing into a hydrocarbon production stream a composition containing an asphaltene inhibitor, wherein the asphaltene inhibitor includes the formula: 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.

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: A method of performing an oilfield treatment that includes delivering to an oilfield fluid a host-guest complex, wherein the host-guest complex is formed from a solution of host molecule mixed with a guest molecule having opposing solubility from the host molecule; wherein the host molecule is present in the solution in an amount of at least 2×10?6 M.

Abstract: An apparatus, such as a compact flotation unit, may include a tank having a fluid inlet. A cylinder may be disposed within the tank and have an open end. A first guide vane may be disposed about the cylinder, with the first guide vane having a portion axially aligned with the fluid inlet. A second guide vane may be disposed about the cylinder adjacent the open end thereof and may include a first end and a second end, with the first end of the second guide vane being axially offset from the second end of the second guide vane.

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 method for measuring particle size distribution in a fluid material, involving inserting a laser beam instrument directly in the fluid flow line, wherein the laser beam instrument focuses a laser beam on a window directly coupled with the fluid flow line, wherein the fluid flow line comprises a fluid having a plurality of particles of different sizes, measuring a diameter of at least one particle in the fluid flow line by reflectance of the at least one particle as the at least one particle passes through the focused laser beam, and determining a duration of reflection of the at least one particle, and obtaining a count of particles in each of a pre-set range group of particle sizes, wherein the count of particles is used to determine particle size distribution in the fluid flow line.

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 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: Methods may include emplacing into a hydrocarbon production stream a composition containing an asphaltene inhibitor, wherein the asphaltene inhibitor includes the formula: 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.

Abstract: An elongate apparatus is disclosed and comprises a material passage and one or more fluid passages. The material passage receives material therethrough. The one or more fluid passages are in fluid communication with the material passage. The material passage and the one or more fluid passages extend substantially parallel throughout the apparatus. A method comprises transferring material in a material passage and further comprises injecting a fluid into the material passage via one or more injection points located along a length of the material passage.

Abstract: A water injection system that includes a primary water injection line; an injection fluid supply tank; a high pressure injection pump in fluid communication with the injection fluid supply and primary water injection line for pumping injection fluid in injection fluid supply tank through the primary water injection line; a polymer gel supply tank; and a high pressure chemical injection pump in fluid communication with the polymer gel supply tank and the water injection line configured to pump polymer gel having a viscosity of at least about 50,000 cP (at 20° C. measured using a Bohlin Rheometer CSR 50, cone and plate measuring system CP 4°/40 mm, single shear rate 1/s) in the polymer gel supply tank into the water injection line for mixture with injection fluid is disclosed.

Abstract: A kinetic gas hydrate inhibitor is provided as a polyester polymer with a plurality of amino or ammonium groups pendent directly from the backbone. A composition containing concentrated kinetic inhibitor is injected into gas wells, or into other systems involving transporting liquid gas mixtures through a conduit. Use of the kinetic inhibitor prevents formation of gas hydrates under conditions of temperature and pressure where they would otherwise occur.

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: 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.