A process for treating drilling fluids which are used during the process of drilling for fossil fuels includes providing a drilling fluid having a continuous hydrocarbon phase, a discontinuous aqueous phase, and a discontinuous solid phase, a polymer solution, at least one coagulant, water, and oil, the oil and water being provided in a volume ratio being from 0.7 to 1.3 times the oil-to-water volume ratio of the drilling fluid. The drilling fluid is mixed with the coagulant, the polymer solution, the oil, and the water in any order to provide an input fluid. The mixture is centrifuged to separate solid materials from the input fluid to provide a treated drilling fluid.

A process for treating drilling fluids which are used during the process of drilling for fossil fuels includes providing a drilling fluid having a continuous hydrocarbon phase, a discontinuous aqueous phase, and a discontinuous solid phase, a polymer solution, at least one coagulant, water, and oil, the oil and water being provided in a volume ratio being from 0.7 to 1.3 times the oil-to-water volume ratio of the drilling fluid. The drilling fluid is mixed with the coagulant, the polymer solution, the oil, and the water in any order to provide an input fluid. The mixture is centrifuged to separate solid materials from the input fluid to provide a treated drilling fluid.

A petroleum coke carbon capture and sequestration method is provided which includes processing the petroleum coke into a petroleum coke particulate, preparing a slurry including the petroleum coke particulate, and injecting the slurry into an underground area. The underground area could be a live crude oil extraction well, where it could displace crude oil, an underground storage facility, a salt formation, or the like.

This invention relates to treated geothermal brine compositions containing reduced concentrations of iron, silica, and manganese compared to the untreated brines. Exemplary compositions contain a concentration of manganese less than 10 mg/kg, a concentration of silica ranging from less than 10 mg/kg, and a concentration of iron less than 10 mg/kg, and the treated geothermal brine is derived from a Saltern Sea geothermal reservoir.

This invention relates to treated geothermal brine compositions containing reduced concentrations of iron, silica, and manganese compared to the untreated brines. Exemplary compositions contain a concentration of manganese less than 10 mg/kg, a concentration of silica ranging from less than 10 mg/kg, and a concentration of iron less than 10 mg/kg, and the treated geothermal brine is derived from a Saltern Sea geothermal reservoir.

An apparatus and methods for characterizing and communicating chemical tracer presence in a subterranean formation traversed by a wellbore including collecting fluid from the wellbore at a wellhead, analyzing the fluid for the presence or concentration or both of the tracer using a gas chromatograph connected to a line collecting the fluid from the wellhead, and communicating the gas chromatograph analysis information within 24 hours of analyzing the fluid. In some embodiments, the tracing chemical is a perfluorocarbon. In some embodiments, the collecting fluid is continuous. Some embodiments condition a flow of fluid. Some embodiments control the collecting, analyzing, and communicating using a controller that may include an autonomous system that includes a multiplex valve that controls for multiple inputs. The multiple inputs may include time, wellhead identity, calibration, signals from the gas chromatograph or the controller, or a combination thereof. Some embodiments may also analyze for the concentration of the tracing chemicals. In some embodiments, the gas chromatograph measures the fluid from the wellbore after a conditioning activity. The conditioning activity may include adjusting the fluid composition, fluid gas to liquid ratio, time between analyzing, phase separation, temperature control, pressure control, or a combination thereof. In some embodiments, the gas chromatograph has a line in direct communication with the wellbore. In some embodiments, communicating includes a transmitter to transmit a signal to a remote device. An apparatus and method for monitoring the presence of a chemical tracer in a fluid produced from a wellbore including continuously collecting and conditioning a sample line from a wellbore, analyzing the sample line with a gas chromatograph at the wellsite, recording information from the analyzing continuously over time; and controlling the collecting, conditioning, analyzing, and recording with a process control device. In some embodiments, the process control device is a microprocessor. Some embodiments communicate information to a remote location. In some embodiments, the collecting, conditioning, analyzing, recording, and communicating occur within 10 minutes or are repeated continuously over 24 hours. Some embodiments may adjust a heater or air conditioner.

An apparatus and methods for characterizing and communicating chemical tracer presence in a subterranean formation traversed by a wellbore including collecting fluid from the wellbore at a wellhead, analyzing the fluid for the presence or concentration or both of the tracer using a gas chromatograph connected to a line collecting the fluid from the wellhead, and communicating the gas chromatograph analysis information within 24 hours of analyzing the fluid. In some embodiments, the tracing chemical is a perfluorocarbon. In some embodiments, the collecting fluid is continuous. Some embodiments condition a flow of fluid. Some embodiments control the collecting, analyzing, and communicating using a controller that may include an autonomous system that includes a multiplex valve that controls for multiple inputs. The multiple inputs may include time, wellhead identity, calibration, signals from the gas chromatograph or the controller, or a combination thereof. Some embodiments may also analyze for the concentration of the tracing chemicals. In some embodiments, the gas chromatograph measures the fluid from the wellbore after a conditioning activity. The conditioning activity may include adjusting the fluid composition, fluid gas to liquid ratio, time between analyzing, phase separation, temperature control, pressure control, or a combination thereof. In some embodiments, the gas chromatograph has a line in direct communication with the wellbore. In some embodiments, communicating includes a transmitter to transmit a signal to a remote device. An apparatus and method for monitoring the presence of a chemical tracer in a fluid produced from a wellbore including continuously collecting and conditioning a sample line from a wellbore, analyzing the sample line with a gas chromatograph at the wellsite, recording information from the analyzing continuously over time; and controlling the collecting, conditioning, analyzing, and recording with a process control device. In some embodiments, the process control device is a microprocessor. Some embodiments communicate information to a remote location. In some embodiments, the collecting, conditioning, analyzing, recording, and communicating occur within 10 minutes or are repeated continuously over 24 hours. Some embodiments may adjust a heater or air conditioner.