Abstract: A method and apparatus includes devices for measuring the liquid rate, pressure, temperature and water cut from a production well, components and devices for diverting a liquid sample into a cylinder vessel, and components and devices for measuring parameters of the separated water phase of the liquid sample. The sample collection and analysis provides a means of significantly improving the accuracy of full-range water cut measurement by providing for improved calibration of a full range water cut meter.

Abstract: A method and apparatus includes devices for measuring the liquid rate, pressure, temperature and water cut from a production well, components and devices for diverting a liquid sample into a cylinder vessel, and components and devices for measuring parameters of the separated water phase of the liquid sample. The sample collection and analysis provides a means of significantly improving the accuracy of full-range water cut measurement by providing for improved calibration of a full range water cut meter.

Abstract: A method and apparatus is disclosed for splitting two-phase liquid-gas flow (e.g., air-water, hydrocarbon gas-condensate, or wet steam) at an impacting pipe-tee junction in a fluid distribution network to maintain constant ratios of liquid mass flow rate to gas (or vapor) mass flow rate entering and exiting the tee junction. Specific mechanical modification of normal impacting tees has been found to significantly increase the range of vapor-phase split ratio for which equal vapor-liquid split ratios (or quality) can be achieved and maintained. In one embodiment, a pre-separator vane is inserted in the entrance arm of the impacting tee. In a second embodiment, nozzles are installed in the exit arms of the impacting tee. In a third embodiment, the impacting tee diameter is increased above that of the surrounding piping leading into and away from the tee junction such that the vapor phase velocity entering the tee junction is less than or equal to 20 ft/sec.

Abstract: A new, improved method is disclosed for reliably and accurately predicting and adjusting vapor-liquid split ratios to branches of a piping network incorporating a plurality of impacting tee junctions for a wide range of two-phase steam or gas-liquid conditions representative of field distribution systems. The vapor velocity and liquid volume fraction of the two-phase entering an impacting tee junction are computed from measured pressure, quality and rate of a two-phase fluid entering the impacting tee junction. The velocities of the vapor split to each branch tee junction are computed from measured or computed vapor mass flow rates. The liquid volume fraction of the two-phase fluid exiting a branch or arm of the tee junction is then computed as a function of inlet vapor velocity and liquid volume fraction and from the vapor velocity exiting the branch or arm using an empirical correlation equation.

Abstract: A method and apparatus for determining the temperature in a wellbore is disclosed. The apparatus is lowered into a wellbore to a desired depth and logged over a selected interval. At least one first heat flux and temperature sensor contacts the wellbore wall. At least one second heat flux and temperature sensor is maintained in contact with the drilling fluid. Comparison of sensor responses provides an accurate determination of the wellbore wall temperature, and a determination of the quality of sensor-wellbore wall contact.

Abstract: A two-phase fluid is metered by injecting a surfactant into the two-phase fluid, homogenizing the fluid and surfactant with either a porous medium or an orifice plate to form a pseudo-single phase fluid, and metering the pseudo-single phase fluid. In one embodiment, both the injection of surfactant and the homogenization with either a porous medium or an orifice plate occur within one foot of where the pseudo-single phase fluid is metered. In another embodiment, the surfactant is injected at a wellhead and the metering occurs downhole.

Abstract: An improved method for deteriming the transit time of a radioactive tracer for steam injection profiles in steam injection wells is disclosed. Radiation decay data is collected at two detectors at different depths. The data is then transformed into a new data set, consisting of time intervals between successive decay events. Tracer radiation decay events are distinguished from background radiation decay events by using statistical methods to establish a high probability that background radiation decay events are excluded. The total set of time intervals are then divided into subgroups of a specified sample size. The arrival time of the tracer is determined as the first time at which a specified minimum number of identified tracer radiation decay events occur successively.

Abstract: The present invention is a method and apparatus for injecting compressible fluids into multiple zones of a hydrocarbon bearing formation, in particular injecting compressible fluid at a predetermined, constant rate into multiple zones through a single tubing string. Producing zones are packed off and limited entry outlets are installed on the injection tubing string at each producing zone. Injection pressure is maintained and limited entry outlets are designed and sized such that the compressible fluid reaches sonic flow through the outlets so that the flow rate no longer responds to changes in downstream pressures.

Abstract: A method for thermal fluid injection into a plurality of strata wherein a well is packed off to establish a first and a second zone. A first tubing string is introduced and is terminated in the first zone. The first tubing string is paralleled by a second tubing string. The first and second tubing strings are physically separated. A first fluid at a first temperature is injected into the first tubing string while a second fluid at a second temperature is simultaneously injected into the second tubing string. The first fluid at the first temperature is applied to the first zone while the second fluid at the second temperature is applied to the second zone.