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 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: 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: 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: 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: 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: 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.

Abstract: A combined degassing and flotation tank for separation of a water influent containing considerable amounts of oil and gas. A rotational flow is created in the tank which forces the lighter components such as oil and gas droplets towards an inner concentric cylindrical wall where they coalesce and rise to the surface of the liquid and are removed via the outlet. The heavier particles are forced down and sink to the lower part where they can be removed as a sludge. The water is discharged via an outlet in the lower part of the tank. The combined degassing and flotation tank is particular suited for use in oil production at sea for removal of oil and gases from water streams before the water is returned to the sea.

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 method of separating includes mixing a fluid into a mixture that has been separated from an oil well stream and that includes water, oil, and gas. The mixture including the fluid is fed into a separator and allowed to separate into a water phase and an oil/fluid phase. The cleaned water phase is removed from the separator via an outlet for water. The oil/fluid phase is subjected to a separation step separating the oil/fluid into an oil phase and a gaseous phase, from which gaseous phase the fluid is recovered by a condensation step and recycled for injection into the mixture. The separator is a liquid-liquid/gas separator in which the pressure is in the range of 0.5 bar to 25 bar, while the mixture including the fluid is separated into the water phase and an oil/gas phase.

Abstract: A system for monitoring fluids at a drilling location, the system including a viscometer (210) having a heating cup and a pump (211) in clued communication with the heating cup, wherein the pump is configured to provide a flow of fluid from a fluid line inlet to the heating cup. The system also including a cleaning fluid tank (214) including communication with the heating cup, wherein the pump is configured to provide a flow of cleaning fluid from the cleaning fluid tank to the heating cup, and a system controller (217) configured to provide instructions to the pump for controlling the flow of cleaning fluid from the cleaning fluid tanks to the heating cup.