Quantifying contamination of downhole samples
Systems, devices, and techniques for determining downhole fluid contamination are disclosed. In one or more embodiments, phase-related properties are measured for a reservoir fluid having a determined composition. An equation-of-state (EOS) is selected and/or tuned based, at least in part, on the measured phase-related properties and the tuned EOS is applied to estimate fluid property values for a reference fluid over specified ranges of at least two thermodynamic properties. Contaminant reference data are generated that correlate the estimated fluid property values for the reference fluid with respective contaminant levels. Within a wellbore, a fluid sample is analyzed to determine a fluid property value. A contaminant level is identified that corresponds within the contaminant reference data to the determined fluid property value of the fluid sample.
1. A method comprising:
measuring fluid property values for a first wellbore fluid obtained at a first sample depth in a wellbore, wherein the first wellbore fluid comprises at least one of a reservoir fluid and a first contaminant;
selecting an equation-of-state from among multiple equations-of-state based, at least in part, on an input range of thermodynamic values;
tuning the equation-of-state based, at least in part, on the fluid property values; and
determining a fluid composition value of the first wellbore fluid based, at least in part, on the tuned equation-of-state.
2. The method of claim 1 , wherein the fluid composition value is a contamination level.
3. The method of claim 1 , further comprising:
generating contaminant reference data based, at least in part, on the measured fluid property values for the first wellbore fluid and the determined fluid composition value of the first wellbore fluid, wherein the contaminant reference data correlates fluid property values to fluid composition.
4. The method of claim 3 , wherein the contaminant reference data further correlates fluid property values and fluid composition to at least one of sample depth in the wellbore, fluid pumpout volume and fluid pumpout time.
5. The method of claim 3 , further comprising:
measuring fluid property values for a second wellbore fluid obtained at a second sample depth in a wellbore, wherein the second wellbore fluid comprises at least one of a reservoir fluid and a second contaminant; and
determining a fluid composition of the second wellbore fluid based, at least in part, on the tuned equation-of-state and the contaminant reference data.
6. The method of claim 5 , wherein determining the fluid composition of the second wellbore fluid further comprises:
tuning the equation-of-state based, at least in part, on the measured fluid property values of the second wellbore fluid.
7. The method of claim 6 , wherein tuning the equation-of-state comprises selecting the equation-of-state based, from among multiple equations-of-state based, at least in part, on an input range of thermodynamic values for the second wellbore fluid.
8. The method of claim 5 , further comprising:
updating the contaminant reference data based, at least in part, on the measured fluid property values for the second wellbore fluid and the determined fluid composition of the second wellbore fluid.
9. The method of claim 8 , further comprising determining an updated fluid composition value of the first wellbore fluid based, at least in part, on the updated contaminant reference data.
10. The method of claim 5 , wherein the first sample depth is the second sample depth.
11. The method of claim 5 , wherein the second contaminant comprises the first contaminant.
12. The method of claim 5 , further comprising:
determining a compositional gradient based, at least in part, on the fluid composition of the first wellbore fluid and the fluid composition of the second wellbore fluid.
13. A non-transitory, machine-readable medium having instructions stored thereon that are executable by a computing device to perform operations comprising:
obtain fluid property values for a first wellbore fluid sampled at a first depth in a wellbore, wherein the first wellbore fluid comprises at least one of a reservoir fluid and a first contaminant;
select a first equation-of-state from among multiple equations-of-state based, at least in part, on an input range of thermodynamic values;
tune the first equation-of-state based, at least in part, on the fluid property values; and
determine a fluid composition value for the first wellbore fluid based, at least in part, on the tuned first equation-of-state.
14. The non-transitory, machine-readable medium of claim 13 , further comprising instructions to:
correlate the fluid property values for the first wellbore fluid and the fluid composition value for the first wellbore fluid; and
generate contaminant reference data based, at least in part, on the correlation.
15. The non-transitory, machine-readable medium of claim 14 , further comprising instructions to:
obtain fluid property values for a second wellbore fluid sampled at a second depth in a wellbore, wherein the second wellbore fluid comprises at least one of a reservoir fluid and a second contaminant; and
determine a fluid composition value for the second wellbore fluid based, at least in part, on the contaminant reference data.
16. The non-transitory, machine-readable medium of claim 15 , further comprising instructions to:
correlate the fluid property values for the second wellbore fluid and the fluid composition value for the second wellbore fluid; and
update the contaminant reference data based, at least in part, on the correlation for the second wellbore fluid.
17. The non-transitory, machine-readable medium of claim 15 , further comprising instructions to:
determine a compositional gradient based, at least in part, on the fluid composition value of the first wellbore fluid and the fluid composition value of the second wellbore fluid and at least one of
a difference between a fluid pumpout volume for the first wellbore fluid and a fluid pumpout volume for the second wellbore fluid,
a difference between a fluid pumpout time for the first wellbore fluid and a fluid pumpout time for the second wellbore fluid;
obtain fluid property values for a third wellbore fluid sampled at a third depth in a wellbore, wherein the third wellbore fluid comprises at least one of a reservoir fluid and a third contaminant; and
estimate a fluid composition value for the third wellbore fluid based, at least in part, on the compositional gradient and at least one of a fluid pumpout volume for the third wellbore fluid and a fluid pumpout time for the third wellbore fluid.
18. The non-transitory, machine-readable medium of claim 17 , further comprising instructions to:
determine a fluid composition value for the third wellbore fluid based, at least in part, on the contaminant reference data; and
determine whether a difference the estimated fluid composition value for the third wellbore fluid to the determined fluid composition value for the third wellbore fluid exceeds a threshold; and
based on a determination that the difference exceeds the threshold,
correlate the fluid property values for the third wellbore fluid and the fluid composition value for the third wellbore fluid; and
update the contaminant reference data based, at least in part, on the correlation for the third wellbore fluid.
19. The non-transitory, machine-readable medium of claim 15 , further comprising instruction to:
obtain fluid property values for a third wellbore fluid sampled at a third depth in a wellbore, wherein the third wellbore fluid comprises at least one of a reservoir fluid and a third contaminant; and
determine a fluid composition value for the third wellbore fluid based, at least in part, on the contaminant reference data and at least one of a fluid pumpout volume for the third wellbore fluid and a fluid pumpout time for the third wellbore fluid,
wherein instructions to correlate the fluid property values for the first wellbore fluid and the fluid composition value for the first wellbore fluid further comprise instruction to correlate the fluid property values for the first wellbore fluid and the fluid composition value for the first wellbore fluid to at least one of a fluid pumpout volume for the first wellbore fluid and a fluid pumpout time for the first wellbore fluid,
wherein instructions to correlate the fluid property values for the second wellbore fluid and the fluid composition value for the second wellbore fluid further comprise instruction to correlate the fluid property values for the second wellbore fluid and the fluid composition value for the second wellbore fluid to at least one of a fluid pumpout volume for the second wellbore fluid and a fluid pumpout time for the second wellbore fluid.
20. The non-transitory, machine-readable medium of claim 15 , wherein instruction to determine the fluid composition value for the second wellbore fluid comprise instruction to:
select a second equation-of-state from among multiple equations-of-state based, at least in part, on an input range of thermodynamic values for the second wellbore fluid;
tune the second equation-of-state based, at least in part, on the fluid property values for the second wellbore fluid; and
determine a fluid composition value for the second wellbore fluid based, at least in part, on the contaminant reference data and the tuned second equation-of-state.
21. A system, comprising:
a wellbore sampling system, wherein the wellbore sampling system obtains at least one wellbore fluid sample;
a fluid analysis system, wherein the fluid analysis system measures at least one fluid property for the at least one wellbore fluid sample;
a processor; and
a machine-readable medium having program code executable by the processor to cause the system to:
obtain fluid property values for a first wellbore fluid sampled at a first depth in a wellbore, wherein the first wellbore fluid comprises at least one of a reservoir fluid and a first contaminant;
select a first equation-of-state from among multiple equations-of-state based, at least in part, on an input range of thermodynamic values;
tune the first equation-of-state based, at least in part, on the fluid property values; and
determine a fluid composition value for the first wellbore fluid based, at least in part, on the tuned first equation-of-state.
22. The system of claim 21 , further comprising machine-readable medium having program code executable by the processor to cause the system to:
correlate the fluid property values for the first wellbore fluid and the fluid composition value for the first wellbore fluid; and
generate contaminant reference data based, at least in part, on the correlation.
23. The system of claim 22 , further comprising machine-readable medium having program code executable by the processor to cause the system to:
obtain fluid property values for a second wellbore fluid sampled at a second depth in a wellbore, wherein the second wellbore fluid comprises at least one of a reservoir fluid and a second contaminant; and
determine a fluid composition value for the second wellbore fluid based, at least in part, on the contaminant reference data.