WET GAS HOLDUP GAS FRACTION AND FLOW METER

1 . A method for determining multi-phase flow properties of a fluid within a pipeline comprising:

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; and

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.

2 . The method of claim 1 ,

wherein the liquid to gas ratio is determined using a sound speed curve, the first time, and the second time.

3 . The method of claim 1 ,

wherein the first transducer and the second transducer are mounted on an outer surface of the pipeline, and the first transducer and the second transducer breach the pipeline to be flush with the inner surface of the pipeline such that the first transducer and the second transducer are in direct contact with the fluid.

4 . The method of claim 1 ,

wherein the first transducer and the second transducer are mounted on opposite sides of an outer surface of the pipeline, and the second transducer is positioned in a location downstream of the first transducer.

5 . The method of claim 1 ,

wherein the fluid is comprised of a gas and a liquid phase and the liquid phase is dispersed in the gas phase as droplets with a minimal amount of stratified flow occurring.

6 . The method of claim 1 ,

wherein a temperature sensor and a pressure sensor are mounted on the pipeline.

7 . The method of claim 1 ,

wherein a control unit with a computer processor is connected to the first transducer and the second transducer to emit the first ultrasonic signal, measure the first time and the second time, and calculate the multi-phase flow properties of the fluid.

8 . A method for determining multi-phase flow properties of a fluid within a pipeline comprising:

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, reflected off of a first surface of a first barrier, reflected off of a second surface of a second barrier, and received back at the first transducer;

measuring a third time for the first ultrasonic signal to be emitted from the first transducer into the fluid, reflected off the second surface of the second barrier, reflected off the first surface of the first barrier, and received back at the first transducer; and

calculating, using the first time, the second time, and the third 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.

9 . The method of claim 8 ,

wherein the liquid to gas ratio is determined using a sound speed curve, the first time, the second time, and the third time.

10 . The method of claim 8 ,

wherein the first transducer is mounted on an outer surface of the pipeline, and the first transducer breaches the pipeline to be flush with the inner surface of the pipeline such that the first transducer is in direct contact with the fluid.

11 . The method of claim 8 ,

wherein the first barrier and the second barrier are mounted to the inner surface of the pipeline and positioned at an angle such that the first surface of the first barrier is directed towards the second surface of the second barrier,

wherein the first barrier and the first transducer are mounted on opposite sides of the pipeline and the first barrier is positioned in a location upstream of the first transducer, and

wherein the second barrier and the first transducer are mounted on opposite sides of the pipeline and the second barrier is positioned in a location downstream of the first transducer.

12 . The method of claim 8 ,

wherein the fluid is comprised of a gas and a liquid phase and the liquid phase is dispersed in the gas phase as droplets with a minimal amount of stratified flow occurring.

13 . The method of claim 8 ,

wherein a temperature sensor and a pressure sensor are mounted on the pipeline.

14 . The method of claim 8 ,

wherein a control unit with a computer processor is connected to the first transducer to emit the first ultrasonic signal, measure the first time, the second time, and the third time, and calculate the multi-phase flow properties of the fluid.

15 . An apparatus for determining multi-phase flow properties of a fluid comprising:

a pipeline configured to be a conduit for the fluid;

a pressure sensor mounted to the pipeline;

a temperature sensor mounted to the pipeline; and

a first transducer, mounted to the pipeline, configured to emit and receive a first ultrasonic signal wherein the first ultrasonic signal reflects off an inner surface of the pipeline to be received back at the first transducer,

wherein a liquid to gas ratio is calculated to monitor well productivity.

16 . The apparatus of claim 15 ,

wherein the fluid is comprised of a gas and a liquid phase and the liquid phase is dispersed in the gas phase as droplets with a minimal amount of stratified flow occurring.

17 . The apparatus of claim 16 further comprising:

a second transducer, mounted to the pipeline, configured to receive the first ultrasonic signal emitted from the first transducer; and

a control unit, with a computer processor, connected to the first transducer and the second transducer to emit the first ultrasonic signal and calculate the multi-phase flow properties of the fluid,

wherein the first transducer and the second transducer are mounted on an outer surface of the pipeline, and the first transducer and the second transducer breach the pipeline to be flush with the inner surface of the pipeline such that the first transducer and the second transducer are in direct contact with the fluid.

18 . The apparatus of claim 17 ,

wherein the first transducer and the second transducer are mounted on opposite sides of the outer surface of the pipeline and the second transducer is positioned in a location downstream of the first transducer.

19 . The apparatus of claim 16 further comprising:

a first barrier comprising a first surface;

a second barrier comprising a second surface; and

a control unit, with a computer processor, connected to the first transducer to emit the first ultrasonic signal and calculate the multi-phase flow properties of the fluid,

wherein the first ultrasonic signal is emitted into the fluid, reflected off of the first surface of the first barrier, reflected off of the second surface of the second barrier, and received back at the first transducer, and

wherein the first ultrasonic signal is emitted into the fluid, reflected off the second surface of the second barrier, reflected off the first surface of the first barrier, and received back at the first transducer.

20 . The apparatus of claim 19 ,

wherein the first barrier and the second barrier are mounted to the inner surface of the pipeline and positioned at an angle such that the first surface of the first barrier is directed towards the second surface of the second barrier,

wherein the first barrier and the first transducer are mounted on opposite sides of the pipeline and the first barrier is positioned in a location upstream of the first transducer, and

wherein the second barrier and the first transducer are mounted on opposite sides of the pipeline and the second barrier is positioned in a location downstream of the first transducer.