FLUID PROPERTIES INCLUDING EQUATION OF STATE MODELING WITH OPTICAL CONSTRAINTS

• US 20130312481A1
• Filed: 12/07/2011
• Published: 11/28/2013
• Est. Priority Date: 12/08/2010
• Status: Abandoned Application

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Pelletier, Michael T., Jones, Christopher M., Wilson, Jim R., Engelman, Robert E.
• Application Number:
  US13/990,210
• Publication Number:
  US 20130312481A1
• Time in Patent Office: Days
• US Class Current: 73/1.02
• CPC Class Codes: E21B 49/08 Obtaining fluid samples or testing fluids, in boreholes or wells
• CPC Class Codes: G01V 11/00 Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00

Abstract

The invention relates to a method of determining an unknown property or information of a reservoir fluid. The method includes measuring a set of responses of a measuring instrument to the fluid and measuring one or more physical or chemical properties of the fluid. The method further includes determining the unknown property or information of the fluid based on the relationship between the instrument responses and the measured properties of the fluid using equation-of-state (EOS) model.

Claims

1-18. -18. (canceled)

19. A method of calibrating a measuring instrument, the method comprising the steps of:

measuring one or more responses of a measuring instrument to a fluid;

obtaining one or more properties of the fluid; and

determining calibration information of the measuring instrument by correlating the instrument responses and the obtained properties of the fluid using equation of state (EOS) model.

20. The method of claim 19, wherein the measuring instrument contains at least one detector and/or sensor selected from the group consisting of a density sensor, capacity sensor, resistivity sensor, viscosity sensor, radioactivity sensor, acoustic sensor, and optical sensor.

21. The method of claim 19, wherein the fluid is a clean sample.

22. The method of claim 19, wherein the fluid is a drilling fluid having a known composition.

23. The method of claim 19, wherein the calibration is absolute calibration.

24. The method of claim 19, wherein one or more constraints are used in the EOS model for calibrating the measuring instrument.

25. The method of claim 19, wherein the calibration is made at or about the same time that the measurements are made.

29. The method of claim 19, wherein the one or more properties of the fluid is selected from the group consisting of dew point, phase envelope, viscosity, density, compressibility, bubble point, saturation pressure, mobility, heat capacity, and thermal conductivity.

30. The method of claim 19, wherein the one or more properties of the fluid is one or more physical properties derived from physical measurements taken downhole in a well.

31. The method of claim 19, wherein the one or more properties of the fluid is one or more chemical properties selected from the group consisting of component concentrations, molecular weight, molecular weight distribution, and gas-to-oil ratio (GOR).