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1. (WO2017003500) DÉTECTION DE GAZ DANS UN FLUIDE DE PUITS DE FORAGE
Note: Texte fondé sur des processus automatiques de reconnaissance optique de caractères. Seule la version PDF a une valeur juridique

WHAT IS CLAIMED IS:

1. A downhole gas detection tool, comprising:

a housing that comprises a connection configured to couple the tool with a drilling string;

a first test module at least partially enclosed within the housing, the first test module comprising a first fluid test chamber operable to fluidly couple to an annulus of a wellbore to receive a first portion of a wellbore fluid, the first test module further comprising an acoustic fluid sensor to measure a fluid acoustic velocity and attenuation of the first portion of the wellbore fluid received in the first fluid test chamber, and a fluid resistivity sensor to measure a fluid resistivity of the first portion of the wellbore fluid received in the first fluid test chamber; and

a second test module at least partially enclosed within the housing, the second test module comprising a second fluid test chamber operable to fluidly couple to the annulus of the wellbore to receive a second portion of the wellbore fluid, the second test module further comprising a pressure-temperature (PT) sensor to measure at least one of a pressure or a temperature of the second portion of the wellbore fluid received in the second fluid test chamber.

2. The downhole gas detection tool of claim 1, wherein the first test module further comprises a target for the acoustic fluid sensor positioned on a side of the first fluid test chamber opposite the acoustic fluid sensor.

3. The downhole gas detection tool of claim 2, wherein the target comprises a portion of the fluid resistivity sensor.

4. The downhole gas detection tool of claim 1, wherein the first test module further comprises a controllable valve in fluid communication with the first fluid test chamber to controllably receive the first portion of the wellbore fluid into the first fluid test chamber, the controllable valve positioned in a fluid pathway that extends between the first fluid test chamber and the housing.

5. The downhole gas detection tool of claim 4, wherein the first test module further comprises a plunger valve, controllable by a centrifugal switch, and positioned to fluidly couple and fluidly decouple the annulus and the controllable valve in the first test module.

6. The downhole gas detection tool of claim 5, wherein the centrifugal switch is operable to adjust the plunger valve between an open position to fluidly couple the annulus and the controllable valve and a closed position to fluidly decouple the annulus and the controllable valve based on rotation of the drilling string.

7. The downhole gas detection tool of claim 1, wherein the first test module further comprises a pressure compensation module positioned in the housing adjacent the acoustic fluid sensor, the pressure compensation module comprising a pressure compensation piston operable to adjust a differential pressure across the acoustic fluid sensor.

8. The downhole gas detection tool of claim 1, wherein the second test module further comprises a controllable valve in fluid communication with the second fluid test chamber to controllably receive the second portion of the wellbore fluid into the second fluid test chamber, the controllable valve positioned in a fluid pathway that extends between the second fluid test chamber and the housing.

9. The downhole gas detection tool of claim 8, wherein the second test module further comprises a plunger valve, controllable by a centrifugal switch, and positioned to fluidly couple and fluidly decouple the annulus and the controllable valve in the second test module.

10. The downhole gas detection tool of claim 9, wherein the centrifugal switch is operable to adjust the plunger valve between an open position to fluidly couple the annulus and the controllable valve and a closed position to fluidly decouple the annulus and the controllable valve based on rotation of the drilling string.

11. The downhole gas detection tool of claim 1, wherein the second test module further comprises a floating piston positioned in the second fluid test chamber and moveable within the second fluid test chamber based on a pressure of the second portion of the wellbore fluid.

12. The downhole gas detection tool of claim 1 1, wherein the second test module further comprises a heater positioned to transfer heat to the second portion of the wellbore fluid.

13. The downhole gas detection tool of claim 1 1, wherein the second test module further comprises a displacement measurement sensor positioned to measure a displacement distance of the floating piston based on the pressure of the second portion of the wellbore fluid.

14. The downhole gas detection tool of claim 1, wherein the wellbore fluid comprises a drilling fluid.

15. A method for detecting gas in a wellbore fluid, comprising:

receiving a first portion of wellbore fluid in a first fluid test chamber of a first test module of the gas detection tool coupled within a downhole tool string in a wellbore;

measuring a fluid resistivity of the first portion of wellbore fluid in the first fluid test chamber of the first test module;

measuring a fluid acoustic velocity and fluid acoustic attenuation of the first portion of wellbore fluid in the first fluid test chamber of the first test module;

receiving a second portion of wellbore fluid in a second fluid test chamber of a second test module of the gas detection tool;

measuring at least one of a pressure or a temperature of the second portion of wellbore fluid in the second test chamber of the second test module; and

determining a presence of a hydrocarbon gas in the wellbore fluid based on at least one of the measured fluid resistivity, fluid acoustic velocity, fluid acoustic attenuation, pressure, or temperature.

16. The method of claim 15, further comprising drilling the wellbore with the downhole tool string.

17. The method of claim 15, wherein receiving the first portion of wellbore fluid in the first fluid test chamber of the first test module of the gas detection tool comprises:

opening a control valve positioned in a fluid pathway that extends between the first fluid test chamber and an exterior housing of the gas detection tool; and

fluidly coupling an annulus of the wellbore with the first fluid test chamber based on opening the valve.

18. The method of claim 17, further comprising:

rotating the downhole tool string in the wellbore;

based on the rotation, opening a plunger valve positioned in the fluid pathway with a centrifugal switch; and

fluidly coupling the annulus of the wellbore with the control valve.

19. The method of claim 15, wherein receiving the second portion of wellbore fluid in the second fluid test chamber of the second test module of the gas detection tool comprises:

opening a control valve positioned in a fluid pathway that extends between the second fluid test chamber and an exterior housing of the gas detection tool;

fluidly coupling an annulus of the wellbore with the second fluid test chamber based on opening the control valve to receive the second portion of wellbore fluid in the second fluid test chamber; and

closing the control valve to seal the second portion of the wellbore fluid in the second fluid test chamber.

20. The method of claim 19, further comprising:

rotating the downhole tool string in the wellbore;

based on the rotation, opening a plunger valve positioned in the fluid pathway with a centrifugal switch; and

fluidly coupling the annulus of the wellbore with the control valve.

21. The method of claim 15, further comprising at least one of:

transmitting the at least one measured fluid resistivity, fluid acoustic velocity, fluid acoustic attenuation, pressure, or temperature from the gas detection tool to a control system located on a terranean surface; or

storing the at least one measured fluid resistivity, fluid acoustic velocity, fluid acoustic attenuation, pressure, or temperature in the gas detection tool.

22. The method of claim 15, wherein measuring at least one of the pressure or the temperature of the second portion of wellbore fluid in the second test chamber of the second test module comprises:

measuring an initial temperature and an initial pressure of the second portion of the wellbore fluid;

heating the second portion of the wellbore fluid a first specified temperature increase; and

measuring, after the heating, a second temperature and a second pressure of the second portion of the wellbore fluid.

23. The method of claim 22, further comprising:

determining a ratio of a pressure differential to a temperature differential of the second portion of the wellbore fluid, the pressure differential comprising a difference between the subsequent pressure and the initial pressure, the temperature differential comprising a difference between the subsequent temperature and the initial temperature; and

determining the presence of the hydrocarbon gas in the wellbore fluid based at least in part on the determined ratio.

24. The method of claim 22, further comprising:

determining that the second portion of wellbore fluid is at a threshold temperature; and

based on the determination, releasing the second portion of wellbore fluid from the second fluid test chamber to the annulus.

25. The method of claim 15, further comprising: based on the determined presence of the hydrocarbon gas in the wellbore fluid, adjusting an operational parameter of the downhole tool string.

26. The method of claim 25, wherein adjusting the operational parameter of the downhole tool string comprises at least one of:

adjusting a rate of penetration of a drill bit of the downhole tool string; or adjusting a geo-direction of the drill bit of the downhole tool string.

27. A well system, comprising:

a drilling string that comprises a downhole gas detection tool, the tool comprising:

an acoustic fluid sensor positioned adjacent a first fluid chamber;

a fluid resistivity sensor positioned adjacent the first fluid chamber; and

a pressure-temperature (PT) positioned adjacent a second fluid chamber; and

a control system communicably coupled to the gas detection tool and operable to perform operations comprising:

operating a first valve during a drilling operation of the drilling string to circulate a drilling fluid into the first fluid chamber;

operating a second valve during the drilling operation of the drilling string to circulate the drilling fluid into the second fluid chamber;

receiving a measurement of at least one of a fluid acoustic velocity, fluid acoustic attenuation, a fluid resistivity, a fluid temperature, or a fluid pressure from the downhole gas detection tool; and

determining a presence of a hydrocarbon gas in the drilling fluid based on the received measurement.

28. The well system of claim 27, wherein the control system is operable to perform further operations comprising:

after receiving a measurement of the fluid temperature and the fluid pressure, operating a heater to heat the drilling fluid in the second fluid chamber;

after heating, receiving another measurement of the fluid temperature and the fluid pressure;

determining a ratio of a fluid temperature differential to a fluid pressure differential based on the measurements of the fluid temperature and the fluid pressure.

29. The well system of claim 27, wherein the control system is operable to perform further operations comprising:

receiving a measurement of a displacement distance of a floating piston in the second fluid chamber based on an increase in the fluid pressure of the drilling fluid in the second fluid chamber; and

determining the presence of the hydrocarbon gas in the drilling fluid based on the received measurement of the displacement distance.

30. The well system of claim 27, wherein the control system is operable to perform further operations comprising:

based on a determination that the pressure differential exceeds a threshold pressure differential, operating at least one pressure compensation piston to adjust a pressure of a pressure compensation chamber adjacent the acoustic fluid sensor to reduce the pressure differential.

31. The well system of claim 27, wherein the control system is operable to perform further operations comprising operating the first and second control valves to release the drilling fluid from the first and second fluid chambers to the annulus.