Real time monitoring and control of downhole reservoirs

• US 5,992,519 A
• Filed: 09/29/1997
• Issued: 11/30/1999
• Est. Priority Date: 09/29/1997
• Status: Expired due to Term

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Thambynayagam, R. K. Michael, Ramakrishnan, Terizhandur S.
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US08/979,907
• Time in Patent Office: 792 Days
• Field of Search: 73/152.01, 73/152.18, 166/250.01, 166/250.07, 166/250.15, 166/52, 166/53, 166/66, 166/373
• US Class Current: 166/250.15
• CPC Class Codes: E21B 43/00 Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells applicable only to water E03B
• CPC Class Codes: E21B 43/12 Methods or apparatus for controlling the flow of the obtained fluid to or in wells E21B43/25 takes precedence; valve arrangements E21B34/00
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
• CPC Class Codes: E21B 47/00 Survey of boreholes or wells monitoring pressure or flow of drilling fluid E21B21/08

Abstract

The method for the active or automated control of the reservoir uses a reservoir model with available data such as seismic, log, and core data as inputs, and uses the reservoir model in conjunction with a reservoir simulation tool in order to determine a production strategy which will maximize certain criteria, e.g., profits. The production strategy may include fixed elements which are not easily altered once the wells go into production, and variable elements which can be adjusted without serious effort during production. The production strategy is implemented by drilling wells, etc., and fluids are then controllably produced from the reservoir according to the variable production strategy; i.e., fluid flow rates are monitored by sensors, and, by adjusting control valves, are kept to desired values (which may change over time) set according to the variable production strategy. According to another aspect of the invention, information gleaned as a result of the adjustments to the control means is used to update the reservoir model. As a result, the variable and fixed production strategies can be updated and implemented.

Claims

1. A method for the active or automated control of a reservoir in a formation, comprising:

a) using a reservoir model, with previously determined information regarding the formation as an input thereto, to determine a preferred production strategy for the reservoir, said preferred production strategy including a desired production flow rate from a well in the formation;

b) producing fluids from the well;

c) using sensing means, monitoring a flow rate at which said fluids are produced from the well;

d) comparing said flow rate of said monitoring with said desired production flow rate to obtain a difference signal; and

e) adjusting a valve control means by minimizing an indication of said difference signal with respect to at least one parameter which relates said difference signal to a valve coefficient of said valve control means, in order to cause said fluids to be produced from the well at substantially said production flow rate according to said production strategy.

2. A method according to claim 1, wherein:

said monitoring a flow rate and said adjusting a valve control means occur in real time.

3. A method according to claim 1, wherein:

said preferred production strategy includes a preferred variable production strategy with a plurality of first parameters, said plurality of first parameters including at least one of a depletion method, a flooding sequence, and said flow rate.

4. A method according to claim 3, wherein:

said preferred production strategy includes a preferred fixed production strategy with a plurality of second parameters including at least one of well spacing, well orientations, and a completion option.

5. A method according to claim 1, wherein:

said reservoir model characterizes the formation into a plurality of geological objects which are assigned properties and values based on said previously determined information.

6. A method according to claim 5, wherein:

said previously determined information includes information obtained from at least one of seismic exploration of said formation, geological coring of said formation, and logging said formation with a borehole tool.

7. A method according to claim 1, wherein:

said reservoir model characterizes the formation into a grid of blocks, each block having assigned properties and values based on said previously determined information.

8. A method according to claim 7, wherein:

said previously determined information includes information obtained from at least one of seismic exploration of said formation, geological coring of said formation, and logging said formation with a borehole tool.

9. A method according to claim 1, wherein:

said using a reservoir model to determine a preferred production strategy includes using a reservoir simulation tool which relies on said reservoir model, and based on said reservoir simulation tool and said reservoir model, conducting an economic evaluation of a plurality of production strategies, with said preferred production strategy being one of said plurality of production strategies.

10. A method according to claim 1, further comprising:

after determining said preferred production strategy, and prior to said producing, drilling wells in said formation based on said preferred production strategy.

11. A method according to claim 1, further comprising:

after determining said preferred production strategy, and prior to said producing, locating said sensors in the well.

12. A method according to claim 1, further comprising:

measuring pressure transients in the well, and using information obtained from said measuring to update said reservoir model.

13. A method according to claim 12, further comprising:

with an updated reservoir model, determining a new preferred production strategy for the reservoir, and

adjusting the control means to cause said fluids to be produced from the well according to said new preferred production strategy.

15. A method according to claim 1, wherein:

said preferred production strategy includes production flow rates from a plurality of wells in the formation,

said producing fluids comprises producing fluids from said plurality of wells;

said monitoring comprises monitoring flow rates at which said fluids are produced from said plurality of wells;

said adjusting a valve control means comprises adjusting control valve means in each of said plurality of wells to cause said fluids to be produced from said plurality of wells at substantially said production flow rates according to said production strategy.

14. A method for the active or automated control of a reservoir in a formation, comprising:

a) using a reservoir model, with previously determined information regarding the formation as an input thereto, to determine a preferred production strategy for the reservoir, said preferred production strategy including a desired production flow rate from a well in the formation;

b) producing fluids from the well;

c) using sensing means, monitoring a flow rate at which said fluids are produced from the well;

d) based on said monitoring, adjusting a control means in order to cause said fluids to be produced from the well at said production flow rate according to said production strategy;

e) measuring pressure transients in the well; and

f) using information obtained from said measuring to update said reservoir model;

with an updated reservoir model, determining a new preferred variable production strategy for the reservoir, and

adjusting the control means to cause said fluids to be produced from the well according to said new preferred variable production strategy.

20. A method according to claim 14, wherein:

said preferred production strategy includes a preferred variable production strategy with a plurality of first parameters, said plurality of first parameters including at least one of a depletion method, a flooding sequence, and said flow rate.

21. A method according to claim 20, further comprising:

with an updated reservoir model, determining a new preferred variable production strategy for the reservoir, and

adjusting the control means to cause said fluids to be produced from the well according to said new preferred variable production strategy.

16. A system for the active or automated control of a reservoir in a formation traversed by a plurality of wells, comprising:

a) a reservoir model means having previously determined information regarding the formation as an input thereto, said reservoir model means for determining a preferred production strategy for the reservoir, said preferred production strategy including a desired production flow rate from at least a designated one of the wells in the formation;

b) production means for producing fluids from the designated well, said production means including adjustable control means for controlling a rate at which the fluids are produced from the designated well; and

c) sensing means for monitoring a flow rate at which the fluids are produced from the designated well, said sensing means being coupled to said adjustable control means in a feedback loop, said adjustable control means including means for comparing said flow rate monitored by said sensing means with said desired production flow rate to obtain a difference signal, and means for minimizing an indication of said difference signal with respect to at least one parameter which relates said difference signal to a valve coefficient of said control means in order to cause said fluids to be produced from the designated well at substantially said production flow rate according to said production strategy.

17. A system according to claim 16, further comprising:

means for measuring pressure transients in the well, wherein indications of said pressure transients are provided to said reservoir model means for updating said reservoir model.

18. A system according to claim 16, wherein:

said preferred production strategy includes a preferred variable production strategy with a plurality of first parameters, said plurality of first parameters including at least one of a depletion method, a flooding sequence, and said flow rate, and

said preferred production strategy includes a preferred fixed production strategy with a plurality of second parameters including at least one of well spacing, well orientations, and a completion option.

19. A system according to claim 16, wherein:

said preferred production strategy includes an injection rate into an injector well of the formation.

22. A system for the active or automated control of a reservoir in a formation traversed by a plurality of wells, comprising:

a) a reservoir model having previously determined information regarding the formation as an input thereto, said reservoir model including (i) means for determining a preferred production strategy for the reservoir, said preferred production strategy including a production flow rate from at least a designated one of the wells in the formation, and (ii) update means for updating said reservoir model based on additional information obtained regarding said designated well;

b) production means for producing fluids from the designated well, said production means including adjustable control means for controlling a rate at which fluids are produced from the designated well;

c) sensing means for monitoring a flow rate at which the fluids are produced from the designated well, said sensing means being coupled to said control means in a feedback loop in order to cause said fluids to be produced from the designated well at said production flow rate according to said production strategy; and

d) means for measuring pressure transients in the designated well, wherein indications of said pressure transients are provided to update means for updating said reservoir model.