Abstract: Wastewater or effluent treatment systems and methods that employ filtering skimmers and/or beaches for separating water from solids and/or other wastes are provided. In some embodiments, the systems include: at least one tank defined by a bottom wall and at least one side wall; a beach including a ramped surface disposed near a side wall of the tank, the ramped surface having a base end disposed at a first elevation relative to the bottom wall of the tank, and a top end opposite the base end at a second elevation relative to the bottom wall of the tank, the second elevation being greater than the first elevation; and a skimmer disposed in the tank that is configured to move material at a surface of the tank toward the beach, wherein (a) at least a portion of the skimmer, (b) at least a portion of the ramped surface of the beach, or (c) at least portions of both the skimmer and the ramped surface of the beach includes a filter material.

Abstract: Wastewater or effluent treatment systems and methods that employ filtering skimmers and/or beaches for separating water from solids and/or other wastes are provided. In some embodiments, the systems include: at least one tank defined by a bottom wall and at least one side wall; a beach including a ramped surface disposed near a side wall of the tank, the ramped surface having a base end disposed at a first elevation relative to the bottom wall of the tank, and a top end opposite the base end at a second elevation relative to the bottom wall of the tank, the second elevation being greater than the first elevation; and a skimmer disposed in the tank that is configured to move material at a surface of the tank toward the beach, wherein (a) at least a portion of the skimmer, (b) at least a portion of the ramped surface of the beach, or (c) at least portions of both the skimmer and the ramped surface of the beach includes a filter material.

Abstract: A method of monitoring and controlling one or more properties of a drilling fluid used in drilling a well is provided. The method comprises circulating the drilling fluid through the wellbore, measuring the specific heat capacity of the drilling fluid, and determining the value of an additional property of the drilling fluid based at least in part on the measured specific heat capacity of the drilling fluid. For example, the additional property of the drilling fluid can be the oil-to-water ratio of the drilling fluid. As another example, the additional property of the drilling fluid can be average specific gravity of the solids in the drilling fluid.

Abstract: A method, system, and apparatus for using and testing chemically tagged drilling fluid additives. In one embodiment, the method comprises: circulating a drilling fluid in a wellbore, wherein the drilling fluid comprises a chemically tagged drilling fluid additive; and extending the wellbore into one or more subterranean formations while circulating the drilling fluid. A system comprising: a drilling fluid comprising a chemically tagged drilling fluid additive; a drill string comprises a drill bit and a downhole tool; a data processing system operable to receive measurements from the downhole tool to produce a visual representation of the chemically tagged drilling fluid additive in a subterranean formation or a filter cake. An apparatus comprising: a vessel for holding a quantity of a drilling fluid a filter media; a mud sensor; a cake sensor; an outlet sensor; a data processing system coupled to the mud sensor, the cake sensor, and the outlet sensor.

Abstract: Methods and apparatuses that measure thermal conductivity and electrical conductivity of a emulsified drilling fluid may be used to indirectly measure the salinity and the average specific gravity of the solids in the emulsified drilling fluid. For example, a drilling assembly may comprise a drill string extending into a wellbore penetrating a subterranean formation; a pump configured to circulate a drilling fluid through the drilling assembly; a first flow line fluidly coupling the wellbore to a retention pit; a second flow line fluidly coupling the retention pit to the pump; a third flow line fluidly coupling the pump to the drill string; and an in-line analysis system fluidly coupled to the retention pit, fluidly coupled to the second flow line, or fluidly coupled to the third flow line, the in-line analysis system comprising a thermal conductivity meter and/or an electrical conductivity meter to a sample container.

Abstract: Methods and apparatuses that measure thermal conductivity and electrical conductivity of a emulsified drilling fluid may be used to indirectly measure the salinity and the average specific gravity of the solids in the emulsified drilling fluid. For example, a drilling assembly may comprise a drill string extending into a wellbore penetrating a subterranean formation; a pump configured to circulate a drilling fluid through the drilling assembly; a first flow line fluidly coupling the wellbore to a retention pit; a second flow line fluidly coupling the retention pit to the pump; a third flow line fluidly coupling the pump to the drill string; and an in-line analysis system fluidly coupled to the retention pit, fluidly coupled to the second flow line, or fluidly coupled to the third flow line, the in-line analysis system comprising a thermal conductivity meter and/or an electrical conductivity meter to a sample container.

Abstract: Methods and apparatuses that measure thermal conductivity and electrical conductivity of a emulsified drilling fluid may be used to indirectly measure the salinity and the average specific gravity of the solids in the emulsified drilling fluid. For example, a drilling assembly may comprise a drill string extending into a wellbore penetrating a subterranean formation; a pump configured to circulate a drilling fluid through the drilling assembly; a first flow line fluidly coupling the wellbore to a retention pit; a second flow line fluidly coupling the retention pit to the pump; a third flow line fluidly coupling the pump to the drill string; and an in-line analysis system fluidly coupled to the retention pit, fluidly coupled to the second flow line, or fluidly coupled to the third flow line, the in-line analysis system comprising a thermal conductivity meter and/or an electrical conductivity meter to a sample container.

Abstract: Beneficiating particulate additives by removing contaminants or minerals that impact the quality and specific gravity of the particulate additives may be achieved via dry solids separation technologies. For example, an air classifier, an electrostatic separator, and a combination thereof may be used to produce a beneficiated particulate additive comprising less than 40% of drill solids by weight of the beneficiated particulate additive.

Abstract: Beneficiating particulate additives by removing contaminants or minerals that impact the quality and specific gravity of the particulate additives may be achieved via dry solids separation technologies. For example, an air classifier, an electrostatic separator, and a combination thereof may be used to produce a beneficiated particulate additive comprising less than 40% of drill solids by weight of the beneficiated particulate additive.

Abstract: Methods and apparatuses that measure thermal conductivity and electrical conductivity of a emulsified drilling fluid may be used to indirectly measure the salinity and the average specific gravity of the solids in the emulsified drilling fluid. For example, a drilling assembly may comprise a drill string extending into a wellbore penetrating a subterranean formation; a pump configured to circulate a drilling fluid through the drilling assembly; a first flow line fluidly coupling the wellbore to a retention pit; a second flow line fluidly coupling the retention pit to the pump; a third flow line fluidly coupling the pump to the drill string; and an in-line analysis system fluidly coupled to the retention pit, fluidly coupled to the second flow line, or fluidly coupled to the third flow line, the in-line analysis system comprising a thermal conductivity meter and/or an electrical conductivity meter to a sample container.

Abstract: Beneficiating particulate additives by removing contaminants or minerals that impact the quality and specific gravity of the particulate additives may be achieved via dry solids separation technologies. For example, an air classifier, an electrostatic separator, and a combination thereof may be used to produce a beneficiated particulate additive comprising less than 40% of drill solids by weight of the beneficiated particulate additive.