Abstract: A method for determining multi-phase flow properties of a fluid is disclosed. The method includes measuring a first time for a first ultrasonic signal to be emitted from a first transducer into the fluid, reflected off an inner surface of the pipeline, and received back at the first transducer. Measuring a second time for the first ultrasonic signal to be emitted from the first transducer into the fluid and received at a second transducer. Calculating, using the first time and the second time, at least one of: a liquid to gas ratio, a fluid density, a gas holdup, a liquid holdup, and a fluid velocity of the fluid flowing through the pipeline.

Abstract: Systems and methods for analyzing a multiphase production fluid includes a pipeline, a fluidic measurement chamber, a pressure sensor, a temperature sensor, an actuating unit, and a fluidic control unit. The actuating unit is partially disposed in the fluidic measurement chamber and is movable between an expansion stage in the fluidic measurement chamber and a compression stage in the fluidic measurement chamber. The fluidic control unit is in communication with the fluidic measurement chamber, the pressure sensor, the temperature sensor, and the actuating unit. The fluidic control unit is configured to communicate with the pipeline to supply the multiphase production fluid to the fluidic measurement chamber. The fluidic control unit is further configured to communicate with the pressure sensor to detect a first pressure of the multiphase production fluid in the fluidic measurement chamber at the expansion stage. 25323135.

Abstract: Systems and methods for analyzing a multiphase production fluid, the system including a pipeline fluidly connected to a fluidic measurement chamber, a pressure sensor, a composite sensor, an actuating unit, and a fluidic control unit. The pipeline is configured to supply the multiphase production fluid to the fluidic measurement chamber. The composite sensor is configured to detect an oil volume and a water volume of the multiphase production fluid in the fluidic measurement chamber. The actuating unit is partially disposed in the fluidic measurement chamber and is movable between a first measurement position in the fluidic measurement chamber and a second measurement position in the fluidic measurement chamber. The fluidic control unit is in communication with the fluidic measurement chamber, the pressure sensor, the composite sensor, and the actuating unit, and is configured to communicate with the pipeline to supply the multiphase production fluid to the fluidic measurement chamber.

Abstract: A system includes a pump to circulate a flow of a fluid from a fluid source through a flow conduit assembly at unique flow rates; a flow meter fluidly coupled within the flow conduit assembly; a coiled tubing assembly fluidly coupled within the flow conduit assembly and including one or more tubing coils; a pressure sensor coupled to the flow conduit assembly and configured to measure a fluid pressure drop across the coiled tubing assembly; and a control system communicably coupled to the flow meter and the pressure sensor. The control system is configured to identify each of the unique flow rates of the flow of fluid through the coiled tubing assembly; identify, for each unique flow rate, the fluid pressure drop across the coiled tubing assembly; for each unique flow rate and corresponding measured fluid pressure drop, determine flow rate-dependent properties of the fluid; and generate a rheogram from the determined flow rate-dependent properties.

Abstract: A method for determining multi-phase flow properties of a fluid is disclosed. The method includes measuring a first time for a first ultrasonic signal to be emitted from a first transducer into the fluid, reflected off an inner surface of the pipeline, and received back at the first transducer. Measuring a second time for the first ultrasonic signal to be emitted from the first transducer into the fluid and received at a second transducer. Calculating, using the first time and the second time, at least one of: a liquid to gas ratio, a fluid density, a gas holdup, a liquid holdup, and a fluid velocity of the fluid flowing through the pipeline.

Abstract: A system and method for targeted delivery of treatment material to a specified depth in a wellbore, including placing a container to the specified depth and allowing the container to fail at the depth due to wellbore pressure to release the treatment material.

Abstract: A system and method for targeted delivery of treatment material to a specified depth in a wellbore, including placing a container to the specified depth and allowing the container to fail at the depth due to wellbore pressure to release the treatment material.