System and method for real time reservoir management

• US RE42,245 E1
• Filed: 05/06/2009
• Issued: 03/22/2011
• Est. Priority Date: 07/20/1999
• Status: Expired due to Term

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Seller, Douglas Donald, Godfrey, Craig William, Thomas, Jacob, Vidrine, William Launey, Wauters, Jerry Wayne
• Primary Examiner(s): Raymond; Edward
• Application Number:
  US12/436,632
• Time in Patent Office: 685 Days
• Field of Search: 702/6, 702/11, 702/12, 702/13, 702/14, 702182-185, 702/188, 702/9, 700/27, 700/28, 700/29, 703/10, 367/73, 166/366, 166/369, 166/52, 166/53, 731/521.8, 731/522.9
• US Class Current: 702/13
• CPC Class Codes: E21B 43/14 Obtaining from a multiple-zone well
• CPC Class Codes: E21B 43/20 Displacing by water

Abstract

A method of real time field wide reservoir management comprising the steps of processing collected field wide reservoir data in accordance with one or more predetermined algorithms to obtain a resultant desired field wide production/injection forecast, generating a signal to one or more individual well control devices instructing the device to increase or decrease flow through the well control device, transmitting the signal to the individual well control device, opening or closing the well control device in response to the signal to increase or decrease the production for one or more selected wells on a real time basis. The system for field wide reservoir management comprising a CPU for processing collected field wide reservoir data, generating a resultant desired field wide production/injection forecast and calculating a target production rate for one or more wells and one or more down hole production/injection control devices.

Claims

1. A method comprising:

receiving data indicative of at least one reservoir characteristic;

determining, in relation to the data, a target production/injection in real time; and

determining a control device setting in relation to the target production/injection.

2. The method of claim 1 further comprising:

allocating the target production/injection between one or more selected reservoir management intervals of the reservoir; and

determining the control device setting for a control device associated with at least one of the selected management intervals in relation to the target production/injection.

3. The method of claim 2 further comprising:

comparing the target production/injection to an actual production/injection; and

determining the control device setting in relation to a difference between the target production/injection and the actual production/injection.

4. The method of claim 1 further comprising:

comparing the target production/injection to an actual production/injection; and

determining the control device setting in relation to a difference between the target production/injection and the actual production/injection.

5. The method of claim 4 wherein determining the control device setting comprises determining the control device setting if a difference between the target production/injection and the actual production/injection is greater than a specified variance.

6. The method of claim 1 wherein determining the control device setting comprises determining the control device setting in real time.

7. The method of claim 1 wherein determining the target production/injection in real time comprises:

monitoring for changes in the data indicative of at least one reservoir characteristic; and

if a change is detected, determining the target production/injection.

8. The method of claim 1 wherein receiving data indicative of at least one reservoir characteristic comprises receiving the data in real time.

9. The method of claim 1 wherein receiving data indicative of at least one reservoir characteristic comprises receiving data indicative of at least geologic data;

and

wherein determining the target production/injection in real time comprises determining a reservoir model adjustment using the data indicative of at least geologic data and determining the target production/injection in relation to the reservoir model.

10. The method of claim 9 wherein determining the reservoir model adjustment comprises determining the reservoir model adjustment in real time.

11. The method of claim 9 further comprising determining the reservoir model adjustment with data indicative of at least one of downhole pressure, flow or temperature.

12. The method of claim 9 further comprising selecting at least one well location based on the reservoir model.

13. The method of claim 1 wherein determining the target production/injection comprises determining the target production/injection using at least one of nodal analysis, material balance calculations, risked economic analysis, or reservoir simulation.

14. The method of claim 1 wherein determining a control device setting comprises determining a setting for at least one of a downhole control device, a surface control device, or a seabed control device.

15. The method of claim 1 wherein receiving data indicative of at least one reservoir characteristic comprises receiving data indicative of at least one of pressure, temperature, viscosity, flow rate, compositional profiles, log data, core data, SDL data, or seismic data.

16. The method of claim 1 wherein determining a control device setting comprises determining a setting for at least a production control device.

17. The method of claim 1 wherein determining, in relation to the data, a target production/injection in real time comprises determining, in relation to the data, the target production/injection continuously.

18. The method of claim 1 wherein determining, in relation to the data, a target production/injection in real time comprises determining the target production/injection based at least in part on the data.

19. The method of claim 1 further comprising communicating the determined control device setting to a control device.

20. The method of claim 19 wherein the control device is remote from the location at which the control device setting is determined.

21. The method of claim 19 wherein communicating the determined control device setting to a control device comprises communicating the determined control device setting over a communication network.

22. The method of claim 21 wherein the communication network is a telephone network.

23. The method of claim 19 wherein communicating the determined control device setting to a control device comprises communicating the control device setting to a person involved in communicating the control device setting to the control device.

24. The method of claim 1 wherein determining the control device setting comprises determining an adjustment to the control device.

25. An article comprising a machine-readable medium storing instructions operable to cause one or more machines to perform operations comprising:

determining, in real time, a target production/injection in relation to received data indicative of at least one reservoir characteristic; and

determining a setting for a control device in relation to the target production/injection.

26. The article of claim 25 wherein the instructions are further operable to cause one or more machines to perform operations comprising:

allocating the target production/injection between one or more selected reservoir management intervals;

determining the control device setting for a control device associated with at least one of the selected management intervals in relation to the target/production injection.

27. The article of claim 26 wherein the instructions are further operable to cause one or more machines to perform operations comprising:

comparing the target production/injection to an actual production/injection; and

determining the control device setting in relation to a difference between the target production/injection and the actual production/injection.

28. The article of claim 25 wherein the instructions are further operable to cause one or more machines to perform operations comprising:

comparing the target production/injection to an actual production/injection; and

determining the control device setting in relation to a difference between the target production/injection and the actual production/injection.

29. The article of claim 28 wherein determining the control device setting comprises determining the control device setting if a difference between the target production/injection and the actual production/injection is greater than a specified variance.

30. The article of claim 25 wherein determining the control device setting comprises determining the control device setting in real time.

31. The article of claim 25 wherein determining the target production/injection in real time comprises:

monitoring for changes in the data indicative of at least one reservoir characteristic; and

if a change is detected, determining the target production/injection.

32. The article of claim 25 wherein the received data indicative of at least one reservoir characteristic is received in real time.

33. The article of claim 25 wherein the received data indicative of at least one reservoir characteristic comprises data indicative of at least geologic data;

and

wherein determining, in real time, a target production/injection comprises determining a reservoir model adjustment using the data indicative of at least geologic data and determining the target production/injection in relation to the reservoir model.

34. The article of claim 33 wherein determining a reservoir model adjustment comprises determining the reservoir model adjustment in real time.

35. The article of claim 33 wherein determining a reservoir model adjustment comprises determining the reservoir model adjustment using further data indicative of at least one of downhole pressure, flow or temperature.

36. The article of claim 33 wherein the instructions are further operable to cause one or more machines to perform operations comprising selecting at least one well location based on the reservoir model.

37. The article of claim 25 wherein determining a target production/injection comprises determining the target production/injection using at least one of model analysis, material balance calculations, risked economic analysis, or reservoir simulation.

38. The article of claim 25 wherein determining a setting for a control device comprises determining a setting for at least one of a downhole control device, a surface control device, or a seabed control device.

39. The article of claim 25 wherein the received data indicative of at least one reservoir characteristic comprises data indicative of at least one of pressure, temperature, viscosity, flow rate, compositional profiles, log data, core data, SDL data, or seismic data.

40. The article of claim 25 wherein determining a setting for a control device comprises determining a setting for at least a production control device.

41. The article of claim 25 wherein determining, in real time, a target production/injection comprises determining a target production/injection continuously.

42. The article of claim 25 wherein determining, in real time a target production/injection in relation to received data comprises determining, in real time a target production/injection based at least in part on the received data.

43. The article of claim 25 wherein the instructions are further operable to cause one or more machines to perform operations comprising:

communicate the setting for the control device to the control device.

44. The article of claim 43 wherein the control device is remote from the location at which the control device setting is determined.

45. The article of claim 43 wherein communicating the determined control device setting to a control device comprises communicating the determined control device setting over a communication network.

46. The article of claim 45 wherein the communication network is telephone network.

47. The article of claim 43 wherein communicating the setting for the control device to the control device comprises communicating the control device setting to a person involved in communicating the control device setting to the control device.

48. The article of claim 25 wherein determining a setting for a control device comprises determining an adjustment to the control device.

49. A system comprising:

at least one processor; and

at least one memory coupled to the processor and storing instructions operable to cause the processor to perform operations comprising;

determining, in real time, a target production/injection in relation to received data indicative of at least one reservoir characteristic; and

determining a setting for a control device in relation to the target production/injection.

50. The system of claim 49 wherein the instructions are further operable to the processor to perform operations comprising:

allocating the target production/injection between one or more selected reservoir management intervals;

determining the control device setting for a control device associated with at least one of the selected management intervals in relation to the target/production injection.

51. The system of claim 50 wherein the instructions are further operable to cause the processor to perform operations comprising:

comparing the target production/injection to an actual production/injection; and

determining the control device setting in relation to a difference between the target production/injection and the actual production/injection.

52. The system of claim 49 wherein the instructions are further operable to cause the processor to perform operations comprising:

comparing the target production/injection to an actual production/injection; and

determining the control device setting in relation to a difference between the target production/injection and the actual production/injection.

53. The system of claim 52 wherein determining the control device setting comprises determining the control device setting if a difference between the target production/injection and the actual production/injection is greater than a specified variance.

54. The system of claim 49 wherein determining the control device setting comprises determining the control device setting in real time.

55. The system of claim 49 wherein determining the target production/injection in real time comprises:

monitoring for changes in the data indicative of at least one reservoir characteristic; and

if a change is detected, determining the target production/injection.

56. The system of claim 49 wherein the received data indicative of at least one reservoir characteristic is received in real time.

57. The system of claim 49 wherein the received data indicative of at least one reservoir characteristic comprises data indicative of at least geologic data;

and

wherein determining, in real time, a target production/injection comprises determining a reservoir model adjustment using the data indicative of at least geologic data and determining the target production/injection in relation to the reservoir model.

58. The system of claim 57 wherein determining a reservoir model adjustment comprises determining the reservoir model adjustment in real time.

59. The system of claim 57 wherein determining a reservoir model adjustment comprises determining the reservoir model adjustment using further data indicative of at least one of downhole pressure, flow or temperature.

60. The system of claim 57 wherein the instructions are further operable to cause the processor to perform operations comprising selecting at least one well location based on the reservoir model.

61. The system of claim 49 wherein determining a target production/injection comprises determining the target production/injection using at least one of nodal analysis, material balance calculations, risked economic analysis, or reservoir simulation.

62. The system of claim 49 wherein determining a setting for a control device comprises determining a setting for at least one of a downhole control device, a surface control device, or a seabed control device.

63. The system of claim 49 wherein the received data indicative of at least one reservoir characteristic comprises data indicative of at least one of pressure, temperature, viscosity, flow rate, compositional profiles, log data, core data, SDL data, or seismic data.

64. The system of claim 49 wherein determining a setting for a control device comprises determining a setting for at least a production control device.

65. The system of claim 49 wherein determining, in real time, a target production/injection comprises determining a target production/injection continuously.

66. The system of claim 49 wherein determining, in real time a target production/injection in relation to received data comprises determining, in real time a target production/injection based at least in part on the received data.

67. The system of claim 49 wherein the instructions are further operable to cause one or more machines to perform operations comprising:

communicate the setting for the control device to a control device.

68. The system of claim 67 wherein the control device is remote from the location at which the control device setting is determined.

69. The system of claim 67 wherein communicating the determined control device setting to a control device comprises communicating the determined control device setting over a communication network.

70. The system of claim 67 wherein the communication network is a telephone network.

71. The system of claim 67 wherein communicating the setting for the control device to the control device comprises communicating the control device setting to a person involved in communicating the control device setting to the control device.

72. The system of claim 49 wherein determining a setting for a control device comprises determining an adjustment to the control device.

73. A method comprising:

monitoring data indicative of at least one reservoir characteristic in real time;

if a variance in the data is detected, updating at least one of a nodal analysis, a material balance analysis, reservoir simulation or risked economics analysis; and

determining a control device setting in relation to at least one of the nodal analysis, material balance analysis, reservoir simulation or risked economics analysis.

74. The method of claim 73 wherein determining a control device setting comprises:

determining a production/injection forecast; and

determining the control device setting in relation to the production/injection forecast.

75. The method of claim 73 wherein determining a control device setting comprises determining a control device setting in real time.

76. The method of claim 73 wherein determining a control device setting comprises determining a setting for at least one of a downhole control device, a surface control device, or a seabed control device.

77. The method of claim 73 wherein determining a control device setting comprises determining a setting for at least a production control device.

78. The method of claim 73 wherein the nodal analysis comprises determining rate versus pressure for a system.

79. The method of claim 73 wherein material balance analysis comprises determining one or more of a hydrocarbon volume, a reservoir drive mechanism and a production profile.

80. The method of claim 73 wherein risked economics analysis comprises determining one or more of rate of economic return, net present value, payout, profit versus investment ratio.

81. A method for developing a reservoir, the method comprising:

performing at least one of, drilling a well that penetrates the reservoir, completing of the well, or producing from the well while drilling;

receiving, in real time, data related to a characteristic of the reservoir from downhole collected during the at least one of drilling a well that penetrates the reservoir, completing of the well, or producing from the well while drilling, wherein the characteristic comprises at least one of temperature, annulus pressure, formation pressure, fluid flow rate, fluid flow type, formation resistivity, permeability, seismics, cross-well acoustic seismometry, porosity, perforation depth, Surface Data Logging (SDL) data, well log data, core data, water saturation data, oil saturation data, clay content data, pressure transient data, skin data, estimated reservoir boundary, hydraulic pressure, hydraulic power, or fluid characteristics;

analyzing the data related to the characteristic of the reservoir;

generating a control signal for a controlled equipment based, at least in part, on the analyzing of the data;

transmitting the control signal to the controlled equipment; and

controlling the controlled equipment for an operation related to the well, using the control signal.

82. The method of claim 81, wherein the transmitting the control signal to the controlled equipment is in real time.

83. The method of claim 81, wherein controlling the controlled equipment for an operation related to the well comprises controlling the controlled equipment for at least one of a downhole operation or a surface operation.

84. The method of claim 81, wherein receiving data related to the characteristic of the reservoir comprises receiving at the surface of the Earth, data related to the characteristic of the reservoir.

85. The method of claim 81, wherein transmitting the control signal to the controlled equipment comprises transmitting, in real time, a control signal from a location at the surface of the Earth to the controlled equipment.

86. The method of claim 81, wherein generating the control signal for the controlled equipment comprises generating the control signal for a downhole apparatus.

87. The method of claim 86, wherein the downhole apparatus comprises a downhole sensor.

88. The method of claim 81, wherein generating the control signal for the controlled equipment comprises generating the control signal for a downhole sensor to collect data for pressure.

89. The method of claim 81, wherein generating the control signal for the controlled equipment comprises generating the control signal for a downhole sensor to collect data for temperature.

90. The method of claim 81, wherein generating the control signal for the controlled equipment comprises generating the control signal for controlling a valve.

91. The method of claim 81, wherein generating the control signal for the controlled equipment comprises generating the control signal for at least one of a downhole control device, a surface control device, or a seabed control device.

92. The method of claim 81, wherein analyzing the data comprises analyzing the data at a location that is remote to the drilling of the well.

93. The method of claim 92, wherein receiving the data related to the characteristic of the reservoir comprises receiving over a communication network, the data related to the characteristic of the reservoir.

94. The method of claim 81, wherein transmitting the control signal to the controlled equipment comprises transmitting the control signal to the controlled equipment over a communication network, the data related to the characteristic of the reservoir.

95. The method of claim 81, wherein seismics comprises cross-well and acoustic seismometry.

96. The method of claim 81, further comprising repeating the operations in real time.

97. The method of claim 81, wherein the characteristic comprises at least one of fluid density, a characteristic derived from data from an ultrasonic sensor, a characteristic derived from data from a low energy density sensor, a characteristic derived from data from a venturi flow meter, a characteristic derived from data from a multi-electrode resistivity sensor, well resistivity tomography, resistivity map, fluid pressure gradients, a pressure boundary, fluid velocity, water production, or gas entry.

98. The method of claim 81, wherein analyzing the data related to the characteristic of the reservoir comprises at least one of analyzing water content to avoid water conning, analyzing resistivity tomography for monitoring movement of flood fronts across a reservoir, mapping a saturation change across a reservoir, analyzing fluid pressure gradients or contours, analyzing pressure boundaries, analyzing zones that have different reservoir pressures, analyzing water production, or analyzing gas entry.

99. A system for developing a reservoir, the system comprising:

a downhole sensor to collect data related to a characteristic of the reservoir, in real time wherein the characteristic comprises at least one of temperature, annulus pressure, formation pressure, fluid flow rate, fluid flow type, formation resistivity, permeability, seismics, cross-well acoustic seismometry, porosity, perforation depth, Surface Data Logging (SDL) data, well log data, core data, water saturation data, oil saturation data, clay content data, pressure transient data, skin data, estimated reservoir boundary, hydraulic pressure, hydraulic power, or fluid characteristics;

a processor at the surface of the Earth to process data related to the characteristic of the reservoir from downhole;

a data base accessible by the processor to store the characteristic of the reservoir; and

a control device that is to receive a control signal from the processor to control an operation related to the reservoir, while drilling a well that penetrates the reservoir.

100. The system of claim 99, wherein the processor to control an operation related to the reservoir comprises the processor to control at least one of a downhole operation or a surface operation.

101. The system of claim 99, wherein the control device is to control the downhole operation during recovery of hydrocarbons from the reservoir while drilling a well for developing the reservoir.

102. The system of claim 99, wherein the downhole sensor comprises a downhole sensor to collect seismic data.

103. The system of claim 99, wherein the downhole sensor comprises a downhole sensor to collect data for temperature.

104. The system of claim 99, wherein the downhole sensor comprises a downhole sensor to collect data for pressure.

105. The system of claim 99, wherein the control device is for at least one of a downhole control device, a surface control device, or a seabed control device.

106. The system of claim 99, wherein the control device is remote from the location of the processor.

107. The system of claim 106, wherein the control device is to receive the control signal over a communication network.

108. The system of claim 107, wherein the communication network is a telephone network.

109. The system of claim 99, wherein seismics comprises cross-well and acoustic seismometry.

110. The system of claim 99, wherein the characteristic comprises at least one of fluid density, a characteristic derived from data from an ultrasonic sensor, a characteristic derived from data from a low energy density sensor, a characteristic derived from data from a venturi flow meter, a characteristic derived from data from a multi-electrode resistivity sensor, well resistivity tomography, resistivity map, fluid pressure gradients, a pressure boundary, fluid velocity, water production, or gas entry.

111. The system of claim 99, wherein the processor is to perform at least one of the following operations:

analyze water content to avoid water conning, analyze resistivity tomography for monitoring movement of flood fronts across a reservoir, map a saturation change across a reservoir, analyze fluid pressure gradients or contours, analyze pressure boundaries, analyze zones that have different reservoir pressures, analyze water production, or analyze gas entry.

112. An article comprising a machine-readable medium storing instructions operable to cause one or more machines to perform operations comprising:

receiving, in real time at the surface of the Earth, data related to a characteristic of a reservoir, wherein the characteristic comprises at least one of temperature, annulus pressure, formation pressure, fluid flow rate, fluid flow type, formation resistivity, permeability, seismics, cross-well acoustic seismometry. porosity, perforation depth, Surface Data Logging (SDL) data, well log data, core data, water saturation data, oil saturation data, clay content data, pressure transient data, skin data, estimated reservoir boundary, hydraulic pressure, hydraulic power, or fluid characteristics;

analyzing the data related to the characteristic of the reservoir;

generating a control signal for a control device for an operation relating to the reservoir based, at least in part, on the analyzing of the data; and

transmitting the control signal to the control device for controlling the control device while drilling of a well for developing the reservoir.

113. The article of claim 112, wherein generating a control signal for a control device for an operation related to the reservoir comprises generating a control signal for a control device to control at least one of a downhole operation, or a surface operation.

114. The article of claim 112, wherein the transmitting the control signal to the control device comprises transmitting the control signal to the control device in real time.

115. The article of claim 112, wherein controlling the control device for the downhole operation occurs, at least in part, during recovery of hydrocarbons from the reservoir while drilling a well for developing the reservoir.

116. The article of claim 112, wherein generating the control signal for the control device comprises generating the control signal for a downhole sensor.

117. The article of claim 112, wherein generating the control signal for the control device comprises generating the control signal for a downhole sensor to collect data for pressure.

118. The article of claim 112, wherein generating the control signal for the control device comprises generating the control signal for a downhole sensor to collect data for temperature.

119. The article of claim 112, wherein generating the control signal for the control device comprises generating the control signal for a valve.

120. The article of claim 112, wherein generating the control signal for the control device comprises generating the control signal for at least one of a downhole control device, a surface control device, or a seabed control device.

121. The article of claim 112, wherein seismics comprises cross-well and acoustic seismometry.

122. The article of claim 112, further comprising repeating the operations in real time.

123. The article of claim 112, wherein the characteristic comprises at least one of fluid density, a characteristic derived from data from an ultrasonic sensor, a characteristic derived from data from a low energy density sensor, a characteristic derived from data from a venturi flow meter, a characteristic derived from data from a multi-electrode resistivity sensor, well resistivity tomography, resistivity map, fluid pressure gradients, a pressure boundary, fluid velocity, water production, or gas entry.

124. The article of claim 112, wherein analyzing the data related to the characteristic of the reservoir comprises at least one of analyzing water content to avoid water conning, analyzing resistivity tomography for monitoring movement of flood fronts across a reservoir, mapping a saturation change across a reservoir, analyzing fluid pressure gradients or contours, analyzing pressure boundaries, analyzing zones that have different reservoir pressures, analyzing water production, or analyzing gas entry.

125. A method for developing a reservoir, the method comprising:

performing the following operations, at least in part, at a location remote from a site of a well being drilled that penetrates the reservoir, from a site of a well being completed, or from a site of a well that is producing from the reservoir while drilling;

receiving data in real time, said data related to a characteristic of the reservoir, wherein the characteristic comprises at least one of temperature, annulus pressure, formation pressure, fluid flow rate, fluid flow type, formation resistivity, permeability, seismics, cross-well acoustic seismometry, porosity, perforation depth, Surface Data Logging (SDL) data, well log data, core data, water saturation data, oil saturation data, clay content data, pressure transient data, skin data, estimated reservoir boundary, hydraulic pressure, hydraulic power, or fluid characteristics;

analyzing, with a computer, the data related to the characteristic of the reservoir.

126. The method of claim 125, further including the operation:

generating, based at least in part on the analyzing of the data, a control signal for a controlled equipment used for drilling the well, completing the well, or producing from the well while drilling.

127. The method of claim 125, wherein the characteristic comprises at least one of fluid density, a characteristic derived from data from an ultrasonic sensor, a characteristic derived from data from a low energy density sensor, a characteristic derived from data from a venturi flow meter, a characteristic derived from data from a multi-electrode resistivity sensor, well resistivity tomography, resistivity map, fluid pressure gradients, a pressure boundary, fluid velocity, water production, or gas entry.

128. The method of claim 126, wherein analyzing the data related to the characteristic of the reservoir comprises at least one of analyzing water content to avoid water conning, analyzing resistivity tomography for monitoring movement of flood fronts across a reservoir, mapping a saturation change across a reservoir, analyzing fluid pressure gradients or contours, analyzing pressure boundaries, analyzing zones that have different reservoir pressures, analyzing water production, or analyzing gas entry.

134. The method of claim 126 further including the operation:

transmitting the control signal to the controlled equipment.

135. The method of claim 134, wherein the analyzing, generating and transmitting operations are in real time.

129. A method for developing a reservoir, the method comprising:

performing at least one of, drilling a well that penetrates the reservoir, completing of the well, or producing from the well while drilling;

receiving, in real time, data related to a characteristic of drilling the well, completing the well or producing from the well while drilling, wherein the characteristic comprises at least one of temperature, annulus pressure, formation pressure, fluid flow rate, fluid flow type, formation resistivity, permeability, seismics, cross-well acoustic seismometry, porosity, perforation depth, Surface Data Logging (SDL) data, well log data, core data, water saturation data, oil saturation data, clay content data, pressure transient data, skin data, estimated reservoir boundary, hydraulic pressure, hydraulic power, or fluid characteristics;

analyzing the data related to the characteristic;

generating a control signal for a flow control device based, at least in part, on the analyzing of the data;

transmitting the control signal to the flow control device; and

controlling the flow control device for an operation related to the well, using the control signal.

130. The method of claim 129, wherein the transmitting the control signal to the controlled equipment is in real time.

131. The method of claim 129, wherein generating the control signal for the flow control device comprises generating the control signal for controlling a valve.

132. The method of claim 129, wherein analyzing the data comprises analyzing the data at a location that is remote to the drilling of the well.

133. The method of claim 129, further comprising repeating the operations in real time.