Coriolis pump-off controller

• US 5,823,262 A
• Filed: 04/10/1996
• Issued: 10/20/1998
• Est. Priority Date: 04/10/1996
• Status: Expired due to Term

• Current Assignee: Micro Motion Incorporated (Emerson Electric Company)
• Original Assignee: Micro Motion Incorporated (Emerson Electric Company)
• Inventors: Dutton, Robert E.
• Primary Examiner(s): Suchfield, George A.
• Application Number:
  US08/629,805
• Time in Patent Office: 923 Days
• Field of Search: 166/250.01, 166/250.08, 166/250.15, 166/267, 166/369, 166/370, 166/53, 166/66, 166/68.5, 166/86.1, 166/91.1, 166/105, 73/152.29, 73/152.32, 73/152.61, 417/36
• US Class Current: 166/250.15
• CPC Class Codes: E21B 43/127 Adaptations of walking-beam pump systems
• CPC Class Codes: E21B 47/009 Monitoring of walking-beam pump systems
• CPC Class Codes: F04B 2201/0201 Position of the piston
• CPC Class Codes: F04B 2205/09 Flow through the pump
• CPC Class Codes: F04B 49/065 and making use of computers
• CPC Class Codes: F04B 49/106 Responsive to pumped volume

Abstract

The operation of an oil well pumping unit control system (20, 200) is governed by a computerized automated control unit (88) that receives flow rate measurements from a Coriolis flow meter (28). The control unit causes production from a beam pumping unit (22) to cease when measurements from the Coriolis flow meter indicate a decline in the pump efficiency. The decline in pump efficiency indicates that a production fluid level (136) in the production tubing (108) has fallen below the uppermost point of travel for the plunger (122). Production from the well is, accordingly, shut-in to afford the reservoir sufficient time to build the pressure and corresponding fluid level that is required to recommence production operations.

Claims

1. A pump control system for use in terminating actuation of a pumping unit while fluid levels in a well bore are disadvantageously low, said system comprising:

means for measuring a production fluid volume corresponding to the reciprocation of a reciprocating pump unit;

means for producing signals representative of said production fluid volume corresponding to each of said stroke cycles;

means responsive to receipt of said signals for comparing said production fluid volumes to identify a reduction in pump stroke lifting efficiency;

means for generating a signal representative of said reduction in pump stroke efficiency; and

means responsive to said generation of said signal representative of said reduction in pump stroke efficiency for stopping surface production from said pumping unit,

wherein said measuring means includes a Coriolis flow meter.

2. The system as set forth in claim 1 wherein said stopping means includes means for delaying actuation of said pumping unit over a sufficient period of time to permit bottom hole pressure to build up in said well bore.

3. The system as set forth in claim 1 wherein said stopping means includes means for reintroducing surface production to said well bore to prevent deposition of sediment on downhole pump system components.

4. The system as set forth in claim 1 wherein said stopping means includes a manifold providing means for increasing pressure on said well'"'"'s flow line.

5. The system as set forth in claim 4 wherein said stopping means includes means responsive to said increased pressure for ceasing actuation of said pumping unit.

6. The system as set forth in claim 1 including means for adjusting pump operation parameters selected from a list consisting of pump strokes per unit time, shut-in time, and pumping time.

7. The system as set forth in claim 1 including means for detecting a problem selected from a group consisting of a check valve leak and a standing valve leak.

8. The system as set forth in claim 7 wherein said detecting means includes means for producing signals representative of a backflow of produced fluids into said well bore.

9. The system as set forth in claim 1 including means for analyzing said signals to identify a problem selected from a group consisting of a tubing leak and a traveling valve leak.

10. The system as set forth in claim 1 wherein said measuring means includes means for calculating said production volume by dividing a mass flow rate by a density value corresponding to said mass flow rate.

11. The system as set forth in claim 1 wherein said comparing means includes means for calculating a difference between successive ones of said signals.

12. A method of controlling a pumping unit to avoid actuation of the pumping unit while fluid levels in a well bore are disadvantageously low, said method comprising the steps of:

measuring a production fluid volume produced by a pumping unit through the use of a Coriolis flow meter;

producing signals representative of said production fluid volume corresponding to each upstroke of said pumping unit;

comparing said signals between one another to identify a reduction in volumetric pump stroke efficiency induced by an upper limit of production fluids in said well bore having fallen below a plunger assembly attached to said pumping unit;

transmitting a signal representative of said condition; and

stopping surface production from said pumping unit to permit buildup of bottom hole pressure in said well bore.

13. The method as set forth in claim 12 wherein said stopping step includes a step of delaying actuation of said pumping unit over a sufficient period of time to permit bottom hole pressure to build up in said well bore.

14. The method as set forth in claim 12 wherein said stopping step includes a step of reintroducing surface production to said well bore to prevent deposition of sediment on downhole pump system components.

15. The method as set forth in claim 12 wherein said stopping step includes a step of using a manifold to increase pressure on said well'"'"'s flow line.

16. The method as set forth in claim 15 wherein said stopping step includes a step of responding to said increased pressure by ceasing actuation of said pumping unit.

17. The method as set forth in claim 12 including a step of adjusting pump operation parameters selected from a list consisting of pump strokes per unit time, shut-in time, and pumping time.

18. The method as set forth in claim 12 including a step of detecting a problem selected from a group consisting of a check valve leak and a standing valve leak.

19. The method as set forth in claim 18 wherein said detecting step includes a step of producing signals representative of a backflow of produced fluids into said well bore.

20. The method as set forth in claim 12 a step of analyzing said signals to identify a problem selected from a group consisting of a tubing leak and a traveling valve leak.

21. The method as set forth in claim 12 wherein said measuring step includes calculating a volumetric flow rate by dividing a mass flow rate by a density value corresponding to said mass flow rate.

22. The method as set forth in claim 12 wherein said comparing step includes a step of calculating a difference between successive ones of said signals.