Claims
- 1. A downhole tool comprising:
a sonde deployed down a wellbore adjacent a surrounding formation; a pressure measuring device associated with the sonde for determining fluid mobility for a location in the formation; a device for measuring a saturation level for the location in the formation; and a relative permeability component for calculating a relative permeability value represented by the permeability value for the location at the saturation level for the location.
- 2. The downhole tool of claim 1, wherein the device for measuring a saturation level comprises an NMR tool.
- 3. The downhole tool of claim 1, wherein the device for measuring a saturation level comprises an resistivity tool.
- 4. The downhole tool of claim 1, further comprising:
an injector for injecting a fluid into the formation.
- 5. A method for determining relative permeability for a formation comprising:
determining a saturation value for a location in a formation; measuring a pressure value for the location in the formation; and determining the relative permeability for the formation from the saturation value and the pressure value at the location in the formation.
- 6. The method of claim 5, further comprising:
performing a nuclear magnetic resonance measurement at the location in the formation; determining viscosity for the location in the formation from the NMR measurement; and computing permeability from the mobility.
- 7. The downhole tool of claim 5, further comprising:
a processor for comparing the mobility from the formation test to the NMR permeability to adjust the NMR parameters.
- 8. A method for calculating formation productivity comprising:
deploying an NMR and pressure measuring device in a borehole adjacent a formation; measuring mobility for a location in the formation by pressure testing; measuring saturation level for the location by NMR; and calculating permeability for the measured mobility and saturation at the formation location.
- 9. The method of claim 8,further comprising:
converting mobility to permeability using viscosity data.
- 10. The method of claim 8, further comprising:
continuing to measure mobility and saturation to calculate permeability at various saturation values until the saturation value stops changing during pumping from the formation for pressure testing.
- 11. The method of claims 10, further comprising:
calculating the irreducible saturation level.
- 12. The method of claim 11, further comprising:
injecting completion fluid into the formation; and calculating the irreducible saturation level.
- 13. The method of claim 11, further comprising:
injecting completion fluid into the formation; and calculating a moveable saturation level.
- 14. The method of claim 8, further comprising:
mixing a hyper-polarized agent in with the a fluid to increase the signal to noise ratio for NMR measurements; and injecting the fluid containing the hyper-polarized agent into the formation.
- 15. The method of claim 8, further comprising:
pumping fluid from the formation through a flow line; and monitoring the flow rate to determine when the flow line is clogged.
- 16. The method of claim 8, further comprising:
measuring the fluid flow in a probe; and comparing the measured fluid flow to a hypothetical fluid flow for the pressure gradient created by the probe to determine if the probe is sealed with the borehole wall.
- 17. The method of claim 8, further comprising:
providing information to an intelligent completion system.
- 18. The method of claim 8, further comprising:
testing fluid in a probe to determine if the fluid is wellbore fluid or formation fluid.
- 19. The method of claim 8, further comprising:
determining an end point permeability for at least one of oil and water.
- 20. The method of claim 5, further comprising:
measuring resistivity for a location in the formation location; monitoring fluid saturation; and computing relative permeability.
- 21. A method for determining relative permeability in a formation comprising:
injecting a fluid having a known viscosity into a formation location; determining saturation level using a tool to determine saturation level in the formation location; measuring pressure responses in the formation; injecting additional fluid into the formation to change the saturation level in the formation; determining saturation levels in the formation; and determining relative permeability.
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This patent application is a continuation in part of and claims priority from U.S. patent application Ser. No. 09/910,209 entitled Apparatus and Method for In Situ Analysis of Formation Fluids by Krueger et al. filed on Jul. 20, 2001, which is incorporated herein by reference in its entirety. This application is related to and claims priority from U.S. patent application Ser. No. 60/369,268 entitled, “Combined NMR and Formation Testing” by Georgi et al. filed on Apr. 2, 2002, which is incorporated herein by reference in its entirety. This application is related to and claims priority from U.S. patent application Ser. No. 60/406,082 entitled, “A Method and Apparatus for Combined NMR and Formation Testing For Assessing Relative Permeability with Formation Testing and Nuclear Magnetic Resonance Testing” by Georgi et al. filed on Aug. 26, 2002, which is incorporated herein by reference in its entirety.
Provisional Applications (2)
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Number |
Date |
Country |
|
60369268 |
Apr 2002 |
US |
|
60406082 |
Aug 2002 |
US |
Continuation in Parts (1)
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Number |
Date |
Country |
Parent |
09910209 |
Jul 2001 |
US |
Child |
10404408 |
Apr 2003 |
US |