Apparatus and Method for Wellhead Testing

• US 20140224006A1
• Filed: 02/12/2014
• Published: 08/14/2014
• Est. Priority Date: 02/13/2013
• Status: Active Grant

• Current Assignee: Phase Dynamics, Inc.
• Original Assignee: Phase Dynamics, Inc.
• Inventors: SCOTT, Bentley N.
• Granted Patent: US 9,856,731 B2
• Time in Patent Office: Days
• US Class Current: 73/152.18
• CPC Class Codes: E21B 49/00 Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• CPC Class Codes: G01F 1/20 by detection of dynamic effects of the flow
• CPC Class Codes: G01F 1/74 Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
• CPC Class Codes: G01F 1/8436 signal processing
• CPC Class Codes: G01F 1/8477 with multiple measuring conduits

Abstract

A wellhead test system comprising: i) a Coriolis mass flow meter configured to receive a flow of a liquid; ii) a water analyzer configured to receive the flow of the liquid; and iii) a controller coupled to the Coriolis mass flow meter and the water analyzer. The controller receives from the Coriolis mass flow meter at least one of: mass flow measurement data, mass density measurement data, and drive gain and also receives from the water analyzer at least one of water frequency measurement data, oil frequency measurement data, and insertion loss measurement data. The controller determines a gas volume fraction (GVF) value and modifies the operation of the Coriolis mass flow meter and the water analyzer based on the GVF value.

Claims

1. A wellhead test system comprising:

a Coriolis mass flow meter configured receive a flow of a liquid;

a water analyzer configured to receive the flow of the liquid; and

a controller coupled to the Coriolis mass flow meter and the water analyzer,

wherein the controller is configured to receive from the Coriolis mass flow meter at least one of;

i) mass flow measurement data, ii) mass density measurement data, and ii) drive gain measurement data, and is further configured to receive from the water analyzer at least one of;

i) water frequency measurement data, ii) oil frequency measurement data, and iii) insertion loss measurement data,

wherein the controller is further configured to determine a gas volume fraction (GVF) value and to modify the operation of at least one of the Coriolis mass flow meter or the water analyzer based on the GVF value.

2. The wellhead test system as set forth in claim 1, wherein the controller determines the GVF value based on measurement data from the water analyzer.

3. The wellhead test system as set forth in claim 2, wherein the controller determines the GVF value based on a combination of the measurement data from water analyzer and measurement data from the Coriolis mass flow meter.

4. The wellhead test system as set forth in claim 1, wherein the controller determines the GVF value based on the at least one of:

i) water frequency measurement data, ii) oil frequency measurement data, and iii) insertion loss measurement data.

5. The wellhead test system as set forth in claim 4, wherein the controller determines the GVF value based on a combination of the least one of:

i) water frequency measurement data, ii) oil frequency measurement data, and iii) insertion loss measurement data and measurement data from the Coriolis mass flow meter.

6. The wellhead test system as set forth in claim 1, wherein the controller determines the percentages of gas, oil and water in the flow of the liquid.

7. The wellhead test system as set forth in claim 1, wherein the controller determines the GVF value based on correlations in the measurement data from the water analyzer.

8. The wellhead test system as set forth in claim 7, wherein the controller determines the GVF value based on correlations in the measurement data from the Coriolis mass flow meter.

9. The wellhead test system as set forth in claim 7, wherein the controller is configured to determine the GVF value by calculating a change in resistivity measured by the water analyzer compared to an initial water salinity value measured with substantially no gas present in the water.

10. The wellhead test system as set forth in claim 1, wherein the controller determines the GVF value by correlating a water percentage at a select salinity level with a corresponding resistivity value.

11. A method of testing liquids at a wellhead comprising:

receiving a flow of the liquid in a Coriolis mass flow meter;

receive the flow of the liquid in a water analyzer;

measuring in the Coriolis mass flow meter at least one of;

i) mass flow measurement data, ii) mass density measurement data, and ii) drive gain measurement data;

measuring in the water analyzer at least one of;

i) water frequency measurement data, ii) oil frequency measurement data, and iii) insertion loss measurement data;

determining a gas volume fraction (GVF) value; and

modifying the operation of the Coriolis mass flow meter and the water analyzer based on the GVF value.

12. The method as set forth in claim 11, wherein determining the GVF value determines the GVF value based on measurement data from the water analyzer.

13. The method as set forth in claim 12, wherein determining the GVF value determines the GFV value based on a combination of the measurement data from water analyzer and measurement data from the Coriolis mass flow meter.

14. The method as set forth in claim 11, wherein determining the GVF value determines the GVF value based on the at least one of:

i) water frequency measurement data, ii) oil frequency measurement data, and iii) insertion loss measurement data.

15. The method as set forth in claim 14, wherein determining the GVF value determines the GVF value based on a combination of the least one of:

i) water frequency measurement data, ii) oil frequency measurement data, and iii) insertion loss measurement data and measurement data from the Coriolis mass flow meter.

16. The method as set forth in claim 11, wherein determining the GVF value determines the percentages of gas, oil and water in the flow of the liquid.

17. The method as set forth in claim 11, wherein determining the GVF value determines the GVF value based on correlations in the measurement data from the water analyzer.

18. The method as set forth in claim 17, wherein determining the GVF value determines the GVF value based on correlations in the measurement data from the Coriolis mass flow meter.

19. The method as set forth in claim 17, wherein determining the GVF value determines the GVF value by calculating a change in resistivity measured by the water analyzer compared to an initial water salinity value measured with substantially no gas present in the water.

20. The method as set forth in claim 11, determining the GVF value determines the GVF value by correlating a water percentage at a select salinity level with a corresponding resistivity value.