Abstract: Methods and apparatus for separating solid particles from a fluid. One preferred embodiment includes a tank for settling particles out of the fluid, a conical chamber at the bottom of the tank, an outlet connected to conical chamber, and a conical auger within the conical chamber. The tank may have a tangential inlet that creates a fluid circulation that exerts a centrifugal force on the solid particles to increase the settling of particles out of the fluid. The tank may have a static spiral on the inner wall that helps small particles coalesce into larger particles that settle faster out of the fluid. The fluid content of the solids removed from the tank may be controlled by varying the rotational speed of the conical auger. The rotational speed of the conical auger may be varied depending on the torque required to rotate the conical auger.

Abstract: Methods and apparatus for separating solid particles from a fluid. One preferred embodiment includes a tank for settling particles out of the fluid, a conical chamber at the bottom of the tank, an outlet connected to conical chamber, and a conical auger within the conical chamber. The tank may have a tangential inlet that creates a fluid circulation that exerts a centrifugal force on the solid particles to increase the settling of particles out of the fluid. The tank may have a static spiral on the inner wall that helps small particles coalesce into larger particles that settle faster out of the fluid. The fluid content of the solids removed from the tank may be controlled by varying the rotational speed of the conical auger. The rotational speed of the conical auger may be varied depending on the torque required to rotate the conical auger.

Abstract: A method for containing drilling waste comprising moving the drilling waste comprising drill cuttings in a container so as to prevent at least a substantial portion of the drill cuttings from adhering to the inside surface of the container. The drilling waste may include drilling fluid, oil, water, drill cuttings, or other substances. The drilling waste may be moved by any means and in any fashion. For example, the container may be rotated to tumble the drilling waste inside. The method may be performed at any location, including at the drilling site or processing facility. The method may also be used during transportation of the drilling waste.

Abstract: A method for processing drilling fluid comprising an oil and water emulsion and solid material includes breaking the emulsion into an oil phase and a water phase, increasing the surface area of the solid material, adsorbing at least some of the water phase to the increased surface area of the solid material, and recovering at least some of the oil phase. The drilling fluid may be moved within a container to break the emulsion and increase the surface area of the solids material. Water phase or solid material may be added to the drilling fluid to maximize the amount of water phase adsorbed into the solid material and minimize the amount of oil phase adsorbed to the solid material. The drilling fluid may be processed while being transported between locations. The solid material may be dried in a thermal dryer to vaporize and recover the water phase and any adsorbed oil phase.

Abstract: An apparatus for separating solids from a drilling fluid that includes a basket having two opposed spaced-apart side walls having first ends and second ends, the first ends spaced apart by an end wall connected to each of the side walls, the basket further including a bottom wall through which a fluid outlet passage is defined, a plurality of screening surfaces having a front edge and a back edge and positioned within the basket between the side walls with each screening surface spaced apart vertically from adjacent screening surfaces and the back edge spaced apart from the end wall of the basket, wherein the back edge of each screening surface is lower than the front edge of the corresponding screening surface, a plurality of weirs, each weir retained along the back edge of a corresponding screening surface and spaced apart from the end wall to define a fluid passage between each weir and the end wall, wherein each weir has a top edge extending to a weir height above the back edge of the corresponding screen

Abstract: An additive that increases the density of fluids containing a sized barite weighting agent. The wellbore fluid has rheological properties comparable to a conventional wellbore fluids but does not exhibit problems with sag and resulting variations in density. An illustrative embodiment is directed to a method for making the sized barite weighting agent and a method for using such sized barite weighting agent in a wellbore fluid. In one preferred embodiment the sized barite weighting agent has a particle diameter between 4 ?m to 15 ?m In another preferred embodiment, the additive has a D50 (by weight) of approximately 1 ?m to 6 ?m. In another preferred embodiment the additive has a D90 (by weight) of approximately 4 ?m to 8 ?m. The additive may be used in any wellbore fluid such as drilling, cementing, completion, packing, work-over (repairing), stimulation, well killing, and spacer fluid.

Abstract: An additive that increases the density of fluids used in a wellbore during the construction or repair of oil, gas, injection, water, or geothermal wells comprises In one illustrative embodiment the additive comprises a weighting agent, and more preferably an ultra-fine weighting agent. Another embodiment includes a wellbore fluid containing an ultra-fine weighting agent that has an increased density with improved suspension stability without a significant viscosity increase. The wellbore fluid as described herein has Theological properties comparable to a conventional wellbore fluid. An illustrative embodiment of the claimed subject matter is further directed to a method for making the ultra-fine weighting agent and a method for using such ultra-fine weighting agent in a wellbore fluid. In one preferred embodiment the additive has a particle diameter between 4 ?m to 15 ?m. In another preferred embodiment, the additive has a D50 of approximately 3 ?m (1 ?m to 6 ?m).

Abstract: An additive that increases the density of fluids containing a sized barite weighting agent. The wellbore fluid has rheological properties comparable to conventional wellbore fluids but does not exhibit problems with sag and resulting variations in density. An illustrative embodiment is directed to a method for making the sized barite weighting agent and a method for using such sized barite weighting agent in a wellbore fluid. In one preferred embodiment the sized barite weighting agent has a particle diameter between 4 ?m to 15 ?m. In another preferred embodiment, the additive has a D50 (by weight) of approximately 1 ?m to 6 ?m. In another preferred embodiment the additive has a D90 (by weight) of approximately 4 ?m to 8 ?m. The additive may be used in any wellbore fluid such as drilling, cementing, completion, packing, work-over (repairing), stimulation, well killing, and spacer fluid.

Abstract: An additive that increases the density of fluids containing a sized barite weighting agent. The wellbore fluid has rheological properties comparable to a conventional wellbore fluids but does not exhibit problems with sag and resulting variations in density. An illustrative embodiment is directed to a method for making the sized barite weighting agent and a method for using such sized barite weighting agent in a wellbore fluid. In one preferred embodiment the sized barite weighting agent has a particle diameter between 4 ?m to 15 ?m In another preferred embodiment, the additive has a D50 (by weight) of approximately 1 ?m to 6 ?m. In another preferred embodiment the additive has a D90 (by weight) of approximately 4 ?m to 8 ?m. The additive may be used in any wellbore fluid such as drilling, cementing, completion, packing, work-over (repairing), stimulation, well killing, and spacer fluid.

Abstract: An additive that increases the density of fluids containing a sized barite weighting agent. The wellbore fluid has rheological properties comparable to a conventional wellbore fluids but does not exhibit problems with sag and resulting variations in density. An illustrative embodiment is directed to a method for making the sized barite weighting agent and a method for using such sized barite weighting agent in a wellbore fluid. In one preferred embodiment the sized barite weighting agent has a particle diameter between 4 ?m to 15 ?m In another preferred embodiment, the additive has a D50 (by weight) of approximately 1 ?m to 6 ?m. In another preferred embodiment the additive has a D90 (by weight) of approximately 4 ?m to 8 ?m. The additive may be used in any wellbore fluid such as drilling, cementing, completion, packing, work-over (repairing), stimulation, well killing, and spacer fluid.

Abstract: A method for removing low gravity solids from an oil-based drilling fluid includes directing the drilling fluid into a first inlet of a first line in fluid communication with a centrifuge, injecting steam into the drilling fluid through a second inlet in the first line, wherein the second inlet is upstream from the centrifuge, directing the commingled drilling fluid and steam into the centrifuge, rotating the centrifuge at a rotational speed sufficient to separate solids from liquids, collecting solids from a solids discharge, and collecting effluent from an effluent outlet, wherein the effluent has low gravity solids in an amount less than 1.5%.

Abstract: Oil-based drilling fluid is prepared for further processing to recover the drilling fluid by pumping the drilling fluid through a flow meter. Surfactant may be added to the drilling fluid by using a dose pump and a flow meter. The drilling fluid and surfactant are then blended by passing them through a static mixer. A flocculating polymer is transferred via dose-pumps to another static mixer where it is blended with the surfactant and drilling fluid mixture. To ensure adequate mixing and reaction, additional mixers are included through which the mixture passes. A centrifuge is used to separate solid particles from the fluid.

Abstract: Oil-based drilling fluid is prepared for further processing to recover the drilling fluid by pumping the drilling fluid through a flow meter. Surfactant may be added to the drilling fluid by using a dose pump and a flow meter. The drilling fluid and surfactant are then blended by passing them through a static mixer. A flocculating polymer is transferred via dose pumps to another static mixer where it is blended with the surfactant and drilling fluid mixture. To ensure adequate mixing and reaction, additional mixers are included through which the mixture passes. A centrifuge is used to separate solid particles from the fluid.

Abstract: A method for harvesting weighting agent fines includes milling weighting agent into a plurality of pieces, classifying the pieces based on size to extract those particles having a particle size less than an acceptable maximum diameter, reclassifying the pieces based on size to extract those particles having a particle size less than an acceptable minimum diameter, collecting the particles having a particle size between the standard acceptable minimum and maximum diameters, and collecting the particles having a particle size less than the acceptable minimum diameter. A system for harvesting weighting agent fines includes a mill to reduce the weighting agent particle size, a first classifier to extract particles having a particle size less than the acceptable maximum diameter, a second classifier to extract particles having a particle size less than the acceptable minimum diameter, a fine particle collection area, and a coarse particle collection area.

Abstract: An apparatus for electrophoretically removing contaminants from an oil-based drilling fluid includes a housing, a drum, a means for rotating the drum, and a scraper head. The drum is retained within the housing above the housing floor. The oil-based drilling fluid is directed along the housing floor, contacting both the housing floor and the drum. A negative charge is applied to the drum and a positive charge is applied to the housing, creating an electrical field through the fluid. Drilling fluid contaminants are attracted to and collect upon the drum outer surface. The means for rotating the drum turns the drum through the fluid and collected contaminants remain on the drum outer surface. The scraper removes the collected contaminants from the drum outer surface as it rotates.

Abstract: A mobile chemical preparation plant and method of managing a chemical inventory is claimed. The mobile chemical preparation plant includes a mobile work area outfitted with a chemical compound preparation unit, a remote processing unit, and a global positioning system. Inventory of one or more chemical agents is also located within the mobile work area. The remote processing unit interfaces, remotely, with a central processing unit to monitor and manage inventory in the mobile work area.

Abstract: A mobile chemical preparation plant and method of managing a chemical inventory is claimed. The mobile chemical preparation plant includes a mobile work area outfitted with a chemical compound preparation unit, a remote processing unit, and a global positioning system. Inventory of one or more chemical agents is also located within the mobile work area. The remote processing unit interfaces, remotely, with a central processing unit to monitor and manage inventory in the mobile work area.

Abstract: An additive that increases the density of fluids used in a wellbore during the construction or repair of oil, gas, injection, water, or geothermal wells comprises a wellbore fluid containing a sized barite weighting agent that has an increased density with improved suspension stability without a significant viscosity increase. The wellbore fluid as described herein has rheological properties comparable to a conventional wellbore fluids but does not exhibit problems with sag and resulting variations in density. An illustrative embodiment of the claimed subject matter is further directed to a method for making the sized barite weighting agent and a method for using such sized barite weighting agent in a wellbore fluid. In one preferred embodiment the sized barite weighting agent has a particle diameter between 4 ?m to 15 ?m. In another preferred embodiment, the additive has a D50 (by weight) of approximately 1 ?m to 6 ?m.

Abstract: An additive that increases the density of fluids used in a wellbore during the construction or repair of oil, gas, injection, water, or geothermal wells comprises a wellbore fluid containing a sized barite weighting agent that has an increased density with improved suspension stability without a significant viscosity increase. The wellbore fluid as described herein has rheological properties comparable to a conventional wellbore fluids but does not exhibit problems with sag and resulting variations in density. An illustrative embodiment of the claimed subject matter is further directed to a method for making the sized barite weighting agent and a method for using such sized barite weighting agent in a wellbore fluid. In one preferred embodiment the sized barite weighting agent has a particle diameter between 4 ?m to 15 ?m. In another preferred embodiment, the additive has a D50 (by weight) of approximately 1 ?m to 6 ?m.

Abstract: An additive that increases the density of fluids used in a wellbore during the construction or repair of oil, gas, injection, water, or geothermal wells comprises a wellbore fluid containing a sized barite weighting agent that has an increased density with improved suspension stability without a significant viscosity increase. The wellbore fluid as described herein has rheological properties comparable to a conventional wellbore fluids but does not exhibit problems with sag and resulting variations in density. An illustrative embodiment of the claimed subject matter is further directed to a method for making the sized barite weighting agent and a method for using such sized barite weighting agent in a wellbore fluid. In one preferred embodiment the sized barite weighting agent has a particle diameter between 4 ?m to 15 ?m. In another preferred embodiment, the additive has a D50 (by weight) of approximately 1 ?m to 6 ?m.