Method and apparatus for the continuous analysis of drilling mud

• US 4,635,735 A
• Filed: 07/06/1984
• Issued: 01/13/1987
• Est. Priority Date: 07/06/1984
• Status: Expired due to Fees

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Crownover, Donald J.
• Primary Examiner(s): Levy, Stuart S.
• Assistant Examiner(s): NOT, DEFINED
• Application Number:
  US06/628,683
• Time in Patent Office: 921 Days
• Field of Search: 175/38, 175/42, 175/48, 175/50, 73/153, 73/155
• US Class Current: 175/48
• CPC Class Codes: E21B 21/067 Separating gases from drilling fluids
• CPC Class Codes: E21B 49/005 Testing the nature of borehole walls or the formation by using drilling mud or cutting data
• CPC Class Codes: E21B 49/08 Obtaining fluid samples or testing fluids, in boreholes or wells
• CPC Class Codes: G01N 2030/8854 involving hydrocarbons

Abstract

An oil well drilling rig (10) recirculates drilling mud which is analyzed continuously by pumping it through a gas separation unit (72) where the gases in the mud become separated and mixed with a carrier gas and are conveyed to gas analyzing devices (196) where the concentration of the different hydrocarbon components of the gases in the mud are continuously measured and the signals representative of these measurements are processed together with mud flow rate, and the carrier gas flow rate or the sample gas flow rate signals in a signal processor (64) to provide a continuous log of gas component concentration during drilling.

Claims

1. In the logging of a well during drilling thereof, the method of producing a logging signal which represents, on a continuous basis, the instantaneous concentration of a given gaseous component in drilling mud as it is being returned from the well, said method comprising the steps of:

continuously subjecting at least a portion of said drilling mud being returned from the well to gas separation to separate gas containing said gaseous component from said portion of the returned mud;

continuously and simultaneously subjecting the separated gas to analysis to produce a gaseous component concentration signal whose value at any instant corresponds to the concentration, at that instant, of said given gaseous component in the separated gas;

producing a continuous mud flow rate signal whose value at each instant corresponds to the rate of flow of drilling mud from which the gas is separated;

producing a continuous gas flow rate signal whose value at each instant corresponds to the rate of flow of gas separated from said drilling mud; and

continuously processing said gaseous component concentration signal, said mud flow rate signal and said gas flow rate signal to provide a continuous logging signal whose value at any instant corresponds to the product of the concentration at that instant of the given gaseous component and the rate of flow at that instant of gas separated from said drilling mud divided by the rate of flow at that instant of the drilling mud.

2. A method according to claim 1 wherein the mud being returned from the well is directed into a header tank and a portion of the mud entering the header tank is pumped through a gas separation unit to separate gas from the mud passing through the gas separation unit.

3. A method according to claim 1 wherein the mud pumped through the gas separation unit is also pumped through a mud analysis unit and is subjected to analysis of its liquid components.

4. A method according to claim 1 wherein a further signal is produced which represents, on a continuous basis, the depth of the well from which the gas containing said different gaseous components was extracted and wherein said further signal is correlated, on a continuous basis, with said logging signal to produce a continuous representation of the logging signal correlated with the depth of the well.

5. A method according to claim 1 wherein different analyses are carried out to produce different logging signals by passing the gas containing said gaseous components through plural spectrophotometers each tuned to a different wavelength corresponding to the spectral absorption characteristic of said different gaseous components.

6. A method according to claim 5 wherein the gas containing said gaseous components is passed through said spectrophotometers in succession.

7. A method according to claim 1 wherein the drilling mud is subjected to gas separation by causing a carrier gas to mix with the mud and the gas contained in the mud.

8. A method according to claim 1 wherein the step of producing a continuous mud flow rate signal is carried out by pumping a selected portion of the drilling mud being returned from the well to a gas separation device and by measuring the rate at which said selected portion is pumped.

9. A method according to claim 1 wherein the step of producing a continuous gas flow rate signal comprises measuring the rate of flow of gas following its separation from the mud and prior to subjecting said gas to analysis.

10. Apparatus for producing a logging signal which represents, on a continuous basis, the instantaneous concentration of a given gaseous component in drilling mud as it is being returned from a well during the drilling thereof, said apparatus comprising:

means for continuously subjecting at least a portion of drilling mud being returned from a well being drilled to gas separation to separate gas containing said gaseous component from said portion of the returned mud;

means for continuously and simultaneously subjecting the separated gas to analysis to produce a gaseous component concentration signal whose value at each instant corresponds to the concentration, at that instant, of said give gaseous component in the separated gas;

means producing a continuous mud flow signal whose value at each instant corresponds to the rate of flow of drilling mud from which the gas is separated;

means for producing a continuous gas flow rate signal whose value at each instant corresponds to the rate of flow of gas separated from said drilling mud; and

means for continuously processing said gaseous component concentration signal, said mud flow rate signal and said gas flow rate signal to provide a continuous logging signal whose value at each instant corresponds to the product of the concentration at that instant of the given gaseous component and the rate of flow at that instant of gas separated from said drilling mud divided by the rate of flow at that instant of the drilling mud.

11. Apparatus according to claim 10 wherein said means for continuously subjecting at least a portion of the drilling mud being returned from a well being drilled to gas separation comprises a header tank into which said mud is directed, a gas separation device and a mud pump connected to pump mud through said gas separation device, said mud pump and gas separation device together having a mud intake and a mud outlet in communication with the mud in said header tank, the mud intake being positioned near the mud inlet of said header tank.

12. Apparatus according to claim 11 wherein a mud analysis unit is connected in line with said mud pump and said gas separation device, said mud analysis unit being constructed to analyze the liquid components of the mud passing therethrough.

13. Apparatus according to claim 10 wherein said apparatus includes a well depth measuring means arranged to produce well depth signals which represent, on a continuous basis the depth of the well being drilled and a signal processing device for correlating on a continuous basis said logging signal and the well depth signals to produce a continuous representation of the logging signal correlated with the depth of the well.

14. Apparatus according to claim 10 wherein said means for subjecting the separated gas to analysis includes a plurality of spectrophotometers each tuned to a different wavelength corresponding to the spectral absorption characteristic of said different gaseous components.

15. Apparatus according to claim 14 wherein said means for subjecting the separated gas to analyses further includes means for directing the gas containing said gaseous components through said spectrophotometers in succession.

16. Apparatus according to claim 15 wherein at least some of said spectrophotometers comprise plural cells arranged in line with each other between an infrared lamp and an infrared detector and means for alternately directing gas through one or more cells to provide different measurement ranges.

17. Apparatus according to claim 10 wherein said means for subjecting mud to gas separation comprises an agitation type device and means arranged to cause a carrier gas to become intermixed with the mud flowing through said agitation type device.

18. Apparatus according to claim 10 wherein said means for continuously processing said gaseous component concentration signal, said mud flow rate signal and said gas flow rate signal comprises a signal processing means for producing signals corresponding to the product of the values of said gaseous component concentration signal and said gas flow rate signal divided by the value of said mud flow rate signal.

19. Apparatus according to claim 10 wherein the means producing a continuous mud flow signal comprises a sensor connected to monitor the speed at which said mud pump is driven.

20. Apparatus according to claim 10 wherein the means producing a continuous gas flow rate signal comprises a gas flow rate sensor connected in a gas flow line interconnecting said gas separation device and said means for subjecting the separated gas to analysis.

21. Apparatus according to claim 20 wherein said gas flow rate sensor is a digital flowmeter.

22. A method of ascertaining the concentration of at least one component of the mud gas in drilling mud during a well drilling operation, said method comprising the steps of:

continuously passing said drilling mud through an agitating type gas separation device;

simultaneously flowing a carrier gas through the mud gas separation device at a rate such that the volume of carrier gas is at least several times greater than the volume of mud gas in the drilling mud;

thoroughly mixing the carrier gas in said mud gas separation device with all of the mud therein as well as with the mud gas contained in the mud;

separating from said mud gas separation device a gas mixture comprising said carrier gas and said mud gas;

subjecting said gas mixture to measurement to produce a component gas signal whose value corresponds to the concentration of said component in said gas mixture;

measuring the volume of said carrier gas which flows into said mud gas separation device to produce a carrier gas signal whose value corresponds to said volume of said carrier gas;

measuring the quantity of the mud which passes through said mud gas separation device to produce a mud quantity signal whose value corresponds to said quantity of mud; and

combining said component gas, carrier gas and mud quantity signals such that the product of the values of the component gas and carries gas signals is divided by the value of the mud quantity signal to produce a concentration signal whose value substantially corresponds to the concentration of said component gas in said drilling mud.

23. A method according to claim 22 wherein the mud is returned from the well and is directed into a header tank and a portion of the mud entering the header tank is pumped through a gas separation unit to separate gas from the mud passing through the gas separation unit.

24. A method according to claim 23 wherein the mud pumped through the gas separation unit is also pumped through a mud analysis unit and is subjected to analysis of its liquid components.

25. A method according to claim 22 wherein a further signal is produced which represent, on a continuous basis, the depth of the well from which the gas containing said different gaseous components was extracted and wherein said further signal is correlated, on a continuous basis, with said concentration signal to produce a continuous representation of the concentration signal correlated with the depth of the well.

26. A method according to claim 22 wherein different analyses are carried out by passing the gas containing said gaseous components through plural spectrophotometers each tuned to a different wavelength corresponding to the spectral absorption characteristic of said different gaseous components.

27. A method according to claim 26 wherein the gas containing said gaseous components passed through said spectrophotometers in succession.

28. A method according to claim 22 wherein the step of measuring the quantity of mud which passes through said mud gas separation device is carried out by continuously pumping mud through said mud separation device and measuring the speed of said pumping.

29. A method according to claim 22 wherein the step of measuring the volume of carrier gas which flows into said mud gas separation device comprises a gas flow rate sensor connected in a gas flow line through which carrier gas flows to said mud gas separation device.

30. A method according to claim 29 wherein said gas flow rate sensor is measured digitally.

31. Apparatus for producing a signal representative of the concentration of at least one component of the mud gas in drilling mud during a well drilling operation, said apparatus comprising:

an agitating type mud gas separation device;

means for passing drilling mud, from a well being drilled, through the mud gas separation device;

means for simultaneously flowing a carrier gas through the mud gas separation device at a rate such that the volume of carrier gas is at least several times greater than the volume of mud gas in the drilling mud, said agitating type mud gas separation device being operative to thoroughly mix the carrier gas with all of the mud therein as well as with the mud gas contained in the mud;

means for separating from said mud gas separation device a gas mixture comprising said carrier gas and said mud gas;

means for measuring the concentration of at least one component of the mud gas in the mixture and producing a component gas signal whose value corresponds to the concentration of said component in said mixture;

means for measuring the volume of said carrier gas which flows into said mud gas separation device and producing a carrier gas signal whose value corresponds to said volume of said gas;

means for measuring the quantity of the mud which passes through said mud gas separation device and producing a mud quantity signal whose value corresponds to said quantity of mud; and

means for combining said component gas, carrier gas, and mud quantity signals such that the product of the values of the component gas and carrier gas signals is divided by the value of the mud quantity signals and for producing a concentration signal whose value substantially corresponds to the concentration of said component in said drilling mud.

32. Apparatus according to claim 31 wherein said gas separation device is connected in series with a mud pump and having a mud inlet and a mud outlet arranged in communication with the mud in a header tank and further arranged with the mud inlet located adjacent a mud intake of said header tank at which mud flows into said header tank the well being drilled.

33. Apparatus according to claim 32 wherein a mud analysis unit is connected in line with said mud pump and said gas separation device, said mud analysis unit being constructed to analyze the liquid components of the mud passing therethrough.

34. Apparatus according to claim 31 wherein said apparatus includes a well depth measuring means arranged to produce well depth signals which represent, on a continuous basis the depth of the well being drilled and a signal processing device for correlating on a continuous basis said concentration signal and the well depth signals to produce a continuous representation of the concentration of said given component correlated with the depth of the well.

35. Apparatus according to claim 34 wherein said means for measuring the concentration of at least one component of the mud gas in the mixture comprises a plurality of spectrophotometers each tuned to a different wavelength corresponding to the spectral absorption characteristic of said different gaseous components.

36. Apparatus according to claim 35 wherein said means or measuring the concentration of at least one component of the mud gas in the mixture includes means for directing the gas containing said gaseous components through said spectrophotometers in succession.

37. Apparatus according to claim 36 wherein at least some of said spectrophotometers comprise plural cells arranged in line with each other between an infrared lamp and an infrared detector and means for alternately directing gas through one or more cells provide different measurement ranges.

38. Apparatus according to claim 31 wherein the means for combining said component gas, carriers gas and mud quantity signals comprises a signal processor constructed and arranged to multiply the values of the component gas and carrier gas signals and to divide said product by the value of the mud quantity signal.

39. A mud gas test system for testing the gases contained in drilling mud returned from a well being drilled, said system comprising:

a gas analyzing device for analyzing gases separated from the drilling mud, a mud gas separation device having a mud inlet, a mud outlet, a carrier gas inlet and a gas mixture outlet, said mud gas separation device being of the type in which carrier gas is mixed with mud passing therethrough to produce a gas mixture with gas contained in the mud, first and second manifolds, means arranged to supply a carrier gas to said first manifold, means, including a first valve, connecting the carrier gas inlet of said mud gas separation device to said first manifold, means, including a second valve, connecting the gas mixture outlet of said mud gas separation device to said second manifold, means including a third valve interconnecting said first and second manifolds and means interconnecting said second manifold and said gas analyzing device.

40. A mud gas test system according to claim 39 wherein said means interconnecting said second manifold and said gas analyzing device includes a fourth valve and wherein at least said first valve is of a switching type for alternately connecting the carrier gas inlet of said mud gas separation device to said first manifold and to exhaust.

41. A mud gas test system according to claim 40 wherein said second valve is of a switching type for alternately connecting the gas mixture outlet of said mud gas separation device to said second manifold and to exhaust.

42. A mud gas test system according to claim 41 wherein a rock gas separation device is connected via fifth and sixth valves, respectively, between said first and second manifolds.

43. A mud gas test system according to claim 42 wherein fifth valve is of a switching type for alternately connecting said rock gas separation device to said first manifold and to exhaust.

44. A mud gas test system according to claim 42 wherein said sixth valve is of a switching type for alternately connecting said rock gas separation device to said second manifold and to exhaust.

45. A mud gas test system according to claim 39 wherein a source of calibration gas is connected via a calibration gas valve to said second manifold.

46. A mud gas test system according to claim 39 wherein said first manifold is connected via a purge gas valve to a purge gas inlet of said gas analyzing device.

47. A method for determining whether hydrocarbons are present in earth formations as a borehole is drilled therethrough by earth-boring apparatus operatively supported by a string of drill pipe in said borehole for progressively excavating said borehole as a drilling mud is circulated downwardly through said drill string and returned to the surface through said borehole and including the steps of:

continuously intermixing an inert gas with at least a portion of said drilling mud returning to the surface while said earth-boring apparatus is progressively excavating said borehole for obtaining a mixed stream of said inert gas and at least a measurable portion of formation hydrocarbons that are entrained in successive portions of said returning drilling mud;

analyzing said mixed stream of gases for obtaining a first measurement representative of the concentration of at least one formation hydrocarbon in successive portions of said mixed stream;

analyzing said inert gas for obtaining a second measurement representative of the concentration of at least said one formation hydrocarbon in said inert gas;

correllating said first and second measurements for providing an output signal representative of the concentration of said formation hydrocarbon entrained in said returning drilling mud; and

plotting said output signals as a function of borehole depth for determining which of said subsurface formations may contain said formation hydrocarbon.

48. The method of claim 47 further including the step of analyzing a hydrocarbon having a known concentration for providing a calibration measurement to correct said first measurement.

49. The method of claim 47 wherein said first measurement is a series of continuous measurements obtained while said borehole is being excavated and said second measurement is a single measurement obtained while one or more additional joints of drill pipe are being coupled to said drill string.

50. The method of claim 49 further including the step of analyzing a hydrocarbon having a known concentration for providing a calibration measurement to correct said first measurement.

51. The method of claim 47 wherein said first measurement is a series of continuous measurements obtained while said borehole is being excavated and said second measurement is a series of periodic measurements successively obtained while additional joints of drill pipe are being successively coupled to said drill string.

52. A method for determining whether hydrocarbons are present in earth formations as a borehole is drilled therethrough by earth-boring apparatus operatively supported by a string of drill pipe in said borehole for progressively excavating said borehole as a drilling mud is circulated downwardly through said drill string and returned to the surface through said borehole and including carrying formation cuttings and entrained formation fluids and including the steps of:

continuously intermixing an inert gas with at least a portion of said drilling mud returning to the surface while said earth-boring apparatus is progressively excavating said borehole for obtaining a first mixed stream of said inert gas and at least a measurable portion of formation fluids that are entrained in successive portions of said returning drilling mud;

analyzing said first mixed streams of gases for obtaining a first measurement representative of the concentration of at least one formation fluid in successive portions of said first mixed stream;

intermixing said inert gas with at least a portion of said cuttings returning to the surface for obtaining a second mixed stream of said inert gas and at least a measurable portion of formation fluids that may be entrained in successive portions of said formation cuttings;

analyzing said second mixed stream of gases for obtaining a second measurement representative of the concentration of at least one formation fluid entrained in successive portions of said formation cuttings;

analyzing said inert gas for obtaining a third measurement representative of the concentration of at least said formation fluid in said inert gas;

correllating said measurements for providing a series of output signals representative of the concentration of said formation fluid entrained in said returning drilling mud and said cuttings; and

plotting said output signals as a function of borehole depth for determining which of said subsurface formations may contain said formation fluid.

53. The method of claim 52 further including the step of analyzing a hydrocarbon having a known concentration for providing a calibration measurement to correct said first measurement.

54. The method of claim 52 wherein said first and second measurements are a series of continuous measurements obtained while said borehole is being excavated and said third measurement is a single measurement obtained while one or more additional joints of drill pipe are being coupled to said drill string.

55. The method of claim 54 further including the step of analyzing a hydrocarbon having a known concentration for providing a calibration measurement to correct said first and second measurements.

56. The method of claim 52 wherein said first and second measurement is a series of continuous measurements obtained while said borehole is being excavated and said third measurement is a series of periodic measurements successively obtained while additional joints of drill pipe are being successively coupled to said drill string.