Mobil Oil Corporation

Laird B Thompson

Robert E Maute

Adam Bednarczyk

David Symmons

Multi-phase fluid flow in a pipeline or other flowline is monitored using a combination of flow type detectors. One set of detectors monitors the interfaces between fluid interfaces and the other monitors the presence of different fluid phases around the periphery of the flowline. The relative volumetric fluid flow rates can be measured by detecting changes in the phase interfaces between two sets of sensor rings using sensors spaced around the flowline with the fluid flow type being detected across the flowline with an annular capacitance detector. The sensor rings typically use ultrasonic transducers for detecting the phase interfaces while the capacitance device indicates the presence (or absence) of different phases around the periphery of the flowline. By combining the outputs of the different detectors, an indication of the flow phenomena in the flowline can be obtained. The flowrate in the line can be measured directly using a concentrically oriented set of hot wire anemometers or a concentrically oriented set of thermopiles spaced equally around the flowline in conjunction with the annular capacitance device.

Method for monitoring three phrase fluid flow in tubulars

A method and apparatus is disclosed to identify fluid hydrocarbon flow rates in a flow line such as a pipeline or a producing oil well having a unidirectional fluid flow including moving an acoustic tool through a flow line. Acoustic energy is transmitted into the fluid flow. The acoustic energy is then received when it is reflected back by interfaces within the fluid flow. The reflected acoustic energy is transformed into electrical signals. The electrical signals are rectified. The amplitude peaks of the rectified electrical signals are determined. The travel times of the amplitude peaks are also determined. The amplitude peaks and the time values are used to determine hydrocarbon gas and the hydrocarbon liquid in the hydrocarbon fluid flow in the oil well. A transducer within the acoustic tool rotates three hundred sixty degrees six times per second. This enables us to obtain holdup and velocities for the total flow around the tool even in non ideal operating conditions such as deviated wells.

Multi-phase fluid flow measurement

A method and apparatus for determining the various components of a multi-phase fluid flow in a defined area includes using an acoustic transceiver tool to direct a beam of acoustic energy toward the fluid flow in a producing well or a horizontal line. A signal is generated when the reflection of the beam of acoustic energy returns and is detected. The signal is rectified and recorded as a measure of oil flow rate within the well. The amplitude peaks are identified and areas around each peak are determined. Two areas of the rectified signal are defined relating to the determined amplitude peaks. The rectified signal under each area is integrated to provide an indication of fluid flow and the strength of the signal reaching the casing. A ratio is determined from the integration results of the two areas. The magnitude of this ratio provides an indication of the extent of the presence of gas in the fluid flow. In an alternate embodiment, the detected signal is rectified and the envelop of the rectified full wavelet of returning signals is taken, reducing the frequency of the signal. The envelop of the reflection signals are recorded as a measure of oil flow rate within the defined area. The amplitude peaks are identified and areas around each peak are defined. Each defined area of the envelop is integrated to determine the portion of the flow that is liquid. A ratio is determined from the integration results of the two areas. The magnitude of this ratio provides an indication of the extent of the presence of gas in the fluid flow.

Acoustic logging to identify oil flow rate

A production logging tool includes a plurality of pads affixed on a log tool so that the pads are located on the outer periphery of the well and are directed toward the borehole center. In the preferred embodiment, eight pads are used, with two groups of four pads, each group is spaced apart on the production log tool. Each set of four includes two pairs spaced opposite each other, all four being placed at ninety degree intervals along the circumference of the wellbore. The second set of four pads are also placed at ninety degree intervals along the circumference of the wellbore, however, the group of pads for the second set are displaced forty-five degrees along the circumference of the wellbore from the group of pads for the first set. Each pad contains two hot wire anemometers for temperature measurement, a capacitor plate and an ultrasonic transducer pointed toward reflective plates mounted on the center of the production log tool. The present invention may also include orientation measuring devices, pressure measuring devices, centralizing equipment, etc. as included in many types of prior art tools.

Pad production log tool

In a borehole logging tool, a hot wire or hot film anemometer measures fluid flow entering or exiting the borehole at the wall of the borehole. The logging tool has open sensing pads mounted on the arms to place the sensor pads at the wall. The sensor pads are open to fluid flow to provide minimum disruption of flow. Other sensors measure flow direction, capacitance, and temperature.

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Dallas, TX, United States of America

Laird B Thompson