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The present generally relates to apparatus and methods for instrumentation associated with a downhole deployment valve or a separate instrumentation sub. In one aspect, a DDV in a casing string is closed in order to isolate an upper section of a wellbore from a lower section. Thereafter, a pressure

The present generally relates to apparatus and methods for instrumentation associated with a downhole deployment valve or a separate instrumentation sub. In one aspect, a DDV in a casing string is closed in order to isolate an upper section of a wellbore from a lower section. Thereafter, a pressure differential above and below the closed valve is measured by downhole instrumentation to facilitate the opening of the valve. In another aspect, the instrumentation in the DDV includes sensors placed above and below a flapper portion of the valve. The pressure differential is communicated to the surface of the well for use in determining what amount of pressurization is needed in the upper portion to safely and effectively open the valve. Additionally, instrumentation associated with the DDV can include pressure, temperature, seismic, acoustic, and proximity sensors to facilitate the use of not only the DDV but also telemetry tools.

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The invention claimed is: 1. An apparatus for monitoring conditions downhole, comprising: a casing string cemented in a wellbore, wherein the casing string comprises a deployment valve configured to substantially obstruct a bore of the casing string in a closed position and to provide a passageway

The invention claimed is: 1. An apparatus for monitoring conditions downhole, comprising: a casing string cemented in a wellbore, wherein the casing string comprises a deployment valve configured to substantially obstruct a bore of the casing string in a closed position and to provide a passageway for a tool to pass through the bore in an open position and the deployment valve is an integral part of the casing string; and an optical sensor operatively connected to the deployment valve for sensing a wellbore parameter. 2. The apparatus of claim 1, wherein the wellbore parameter is an operating parameter of the deployment valve. 3. The apparatus of claim 1, wherein the wellbore parameter is selected from a group of parameters consisting of: a pressure, a temperature, and a fluid composition. 4. The apparatus of claim 1, wherein the wellbore parameter is a seismic wave. 5. The apparatus of claim 1, further comprising a control member for controlling an operating parameter of the deployment valve. 6. The apparatus of claim 5, wherein the operating parameter is selected from a group of operations consisting of: opening the valve, closing the valve, equalizing a pressure, and relaying the wellbore parameter. 7. The apparatus of claim 1, wherein the wellbore parameter is a seismic acoustic wave transmitted into a formation from a seismic source. 8. The apparatus of claim 7, wherein the seismic source is located within a drill string in a wellbore. 9. The apparatus of claim 7, wherein the seismic source is located at a surface of a wellbore. 10. The apparatus of claim 7, wherein the deployment valve is located within a first wellbore and the seismic source is located within a second wellbore. 11. The apparatus of claim 7, wherein the seismic source is a vibration of a wellbore tool against a wellbore. 12. A method for measuring wellbore or formation parameters, comprising: placing a downhole tool within a wellbore, the downhole tool comprising: a casing string, at least a portion of the casing string comprising a downhole deployment valve, and an optical sensor disposed on the casing string; cementing the casing string within the wellbore; and lowering a drill string into the wellbore while sensing wellbore or formation parameters with the optical sensor. 13. The method of claim 12, further comprising adjusting a trajectory of the drill string while lowering the drill string into the wellbore. 14. The method of claim 12, further comprising adjusting a composition or amount of drilling fluid while lowering the drill string into the wellbore. 15. The method of claim 12, wherein sensing wellbore or formation parameters with the optical sensor comprises receiving at least one acoustic wave transmitted into a formation from a seismic source. 16. The method of claim 15, wherein the seismic source transmits the at least one acoustic wave from the drill string to the optical sensor. 17. The method of claim 15, wherein the seismic source transmits the at least one acoustic wave from a surface of the wellbore to the optical sensor. 18. The method of claim 15, wherein the seismic source transmits the at least one acoustic wave from an adjacent wellbore to the optical sensor. 19. The method of claim 15, wherein the seismic source transmits the at least one acoustic wave from the drill string vibrating against the wellbore to the optical sensor. 20. The method of claim 12, further comprising selectively obstructing a fluid flow path within the casing string with the downhole deployment valve while lowering the drill string. 21. An apparatus for monitoring conditions within a wellbore or a formation, comprising: a casing string cemented in the wellbore, at least a portion of the casing string comprising a downhole deployment valve for selectively obstructing a fluid path through the casing string; at least one optical sensor disposed on the casing string for sensing one or more parameters within the wellbore or formation; and a control line substantially parallel to an optical line connecting a surface monitoring and control unit to the downhole deployment valve, wherein at least a portion of the control line and the optical line are protected by at least one housing disposed around the casing string. 22. The apparatus of claim 21, wherein the at least one optical sensor comprises at least one of a seismic sensor, acoustic sensor, pressure sensor, or temperature sensor. 23. The apparatus of claim 21, further comprising a seismic source for transmitting at least one acoustic wave into the formation for sensing by the optical sensor. 24. The apparatus of claim 23, wherein the seismic source is disposed within a drill string within the casing string. 25. The apparatus of claim 23, wherein the seismic source is disposed at a surface of a wellbore. 26. The apparatus of claim 23, wherein the seismic source is disposed in an adjacent wellbore. 27. The apparatus of claim 23, wherein the seismic source is vibration of a drill string within the casing string. 28. The apparatus of claim 21, further comprising additional optical sensors disposed on the outside of the casing string and in communication with an optical line for monitoring conditions at different locations within the wellbore or formation. 29. The apparatus of claim 21, wherein the casing string further comprises a flow meter having one or more optical sensors thereon for measuring at least one of a flow rate of a fluid flow through the casing string and a composition of the fluid. 30. A method for permanently monitoring at least one wellbore or formation parameter, comprising: placing a casing string within a wellbore, at least a portion of the casing string comprising a downhole deployment valve with at least one optical sensor disposed therein, wherein the downhole deployment valve is an integral part of the casing string; cementing the casing string in the wellbore; operating the deployment valve between closed and open positions, wherein the closed position substantially obstructs a bore of the casing string and the open position provides a passageway for a tool to pass through the bore; and sensing at least one wellbore or formation parameter with the optical sensor. 31. The method of claim 30, wherein a seismic source transmits at least one acoustic wave into the formation for sensing by the at least one optical sensor. 32. The method of claim 31, wherein the seismic source is disposed at a surface of the wellbore. 33. The method of claim 32, wherein the seismic source is moved to at least two locations at the surface to transmit a plurality of acoustic waves into the formation. 34. The method of claim 30, wherein the at least one wellbore or formation parameter comprises microseismic measurements. 35. The method of claim 30, wherein the at least one optical sensor comprises a seismic sensor, pressure sensor, temperature sensor, or acoustic sensor. 36. The method of claim 30, wherein the casing string further comprises a flow meter and wherein the flow meter senses at least one of a flow rate of fluid and a composition of the fluid. 37. A method for determining flow characteristics of a fluid flowing through a casing string, comprising: providing a casing string cemented within a wellbore, the casing string comprising a downhole deployment valve and at least one optical sensor coupled thereto, wherein the downhole deployment valve is an integral part of the casing string; measuring characteristics of fluid flowing through the casing string using the at least one optical sensor; and determining at least one of a volumetric phase fraction for the fluid and flow rate for the fluid based on the measured fluid characteristics. 38. The method of claim 37, wherein the fluid is introduced while drilling into a formation. 39. The method of claim 38, further comprising adjusting the flow rate of the fluid while drilling into the formation. 40. The method of claim 38, further comprising using the at least one of the volumetric phase fraction and the flow rate to determine formation properties while drilling into the formation. 41. An apparatus for determining flow characteristics of a fluid flowing through a casing string in a wellbore, comprising: a casing string cemented in the wellbore, the casing string comprising a downhole deployment valve, wherein the downhole deployment valve is an integral part of the casing string; and at least one optical sensor coupled to the casing string for sensing at least one of a volumetric phase fraction of the fluid and a flow rate of the fluid through the casing string. 42. The apparatus of claim 41, wherein the fluid comprises drilling fluid introduced into the casing string while drilling into a formation. 43. The apparatus of claim 41, wherein the casing string further comprises one or more optical sensors attached thereto for detecting the position of the downhole deployment valve. 44. An apparatus for downhole monitoring, comprising: a casing string cemented in the wellbore, the casing string comprising a downhole deployment valve, the deployment valve comprising: a housing having a fluid flow path therethrough; a valve member operatively connected to the housing for selectively obstructing the flow path; and an optical sensor physically connected to the housing, wherein the sensor is adapted to enable sensing a seismic wave. 45. The apparatus of claim 44, further comprising a seismic source for transmitting the seismic wave into a formation. 46. An apparatus for monitoring conditions downhole, comprising: a casing string cemented in a wellbore, wherein the casing string comprises a deployment valve configured to substantially obstruct a bore of the casing string in a closed position and to provide a passageway for a tool to pass through the bore in an open position; and an optical sensor operatively connected to the deployment valve for sensing a wellbore parameter, wherein the wellbore parameter is a seismic wave. 47. An apparatus for monitoring conditions downhole, comprising: a casing string cemented in a wellbore, wherein the casing string comprises a deployment valve configured to substantially obstruct a bore of the casing string in a closed position and to provide a passageway for a tool to pass through the bore in an open position; and an optical sensor operatively connected to the deployment valve for sensing a wellbore parameter, wherein the wellbore parameter is a seismic acoustic wave transmitted into a formation from a seismic source. 48. The apparatus of claim 47, wherein the seismic source is located within a drill string in a wellbore. 49. The apparatus of claim 47, wherein the seismic source is a vibration of a wellbore tool against a wellbore. 50. A method for permanently monitoring at least one wellbore or formation parameter, comprising: placing a casing string within a wellbore, at least a portion of the casing string comprising a downhole deployment valve with at least one optical sensor disposed therein; cementing the casing string in the wellbore; operating the deployment valve between closed and open positions, wherein the closed position substantially obstructs a bore of the casing string and the open position provides a passageway for a tool to pass through the bore; and sensing at least one wellbore or formation parameter with the optical sensor, wherein a seismic source transmits at least one acoustic wave into the formation for sensing by the at least one optical sensor. 51. A method for permanently monitoring at least one wellbore or formation parameter, comprising: placing a casing string within a wellbore, at least a portion of the casing string comprising a downhole deployment valve with at least one optical sensor disposed therein; cementing the casing string in the wellbore; operating the deployment valve between closed and open positions, wherein the closed position substantially obstructs a bore of the casing string and the open position provides a passageway for a tool to pass through the bore; and sensing at least one wellbore or formation parameter with the optical sensor, wherein the at least one wellbore or formation parameter comprises microseismic measurements. 52. A method for permanently monitoring at least one wellbore or formation parameter, comprising: placing a casing string within a wellbore, at least a portion of the casing string comprising a downhole deployment valve with at least one optical sensor disposed therein and a flow meter, wherein the flow meter senses at least one of a flow rate of fluid or a composition of the fluid; cementing the casing string in the wellbore; operating the deployment valve between closed and open positions, wherein the closed position substantially obstructs a bore of the casing string and the open position provides a passageway for a tool to pass through the bore; and sensing at least one wellbore or formation parameter with the optical sensor. 53. A method for determining flow characteristics of a fluid flowing through a casing string, comprising: providing a casing string cemented within a wellbore, the casing string comprising a downhole deployment valve and at least one optical sensor coupled thereto; measuring characteristics of fluid flowing through the casing string using the at least one optical sensor, wherein the fluid is introduced while drilling into a formation; determining at least one of a volumetric phase fraction for the fluid and flow rate for the fluid based on the measured fluid characteristics; and adjusting the flow rate of the fluid while drilling into the formation. 54. An apparatus for determining flow characteristics of a fluid flowing through a casing string in a wellbore, comprising: a casing string cemented in the wellbore, the casing string comprising a downhole deployment valve and one or more optical sensors attached thereto for detecting the position of the downhole deployment valve; and at least one optical sensor coupled to the casing string for sensing at least one of a volumetric phase fraction of the fluid and a flow rate of the fluid through the casing string. 55. A method of using a down hole deployment valve (DDV) in a wellbore extending to a first depth, the method comprising: assembling the DDV as part of a tubular string, the DDV comprising: a valve member movable between an open and a closed position; an axial bore therethrough in communication with an axial bore of the tubular string when the valve member is in the open position, the valve member substantially sealing a first portion of the tubular string bore from a second portion of the tubular string bore when the valve member is in the closed position; and an optical sensor configured to sense a parameter of the DDV, a parameter of the wellbore, or a parameter of a formation; running the tubular string into the wellbore; and running a drill string through the tubular string bore and the DDV bore, the drill string comprising a drill bit located at an axial end thereof; and drilling the wellbore to a second depth using the drill string and the drill bit. 56. The method of claim 55, wherein the wellbore is drilled in an underbalanced or near underbalanced condition. 57. The method of claim 55, wherein the DDV axial bore has a diameter substantially equal to the diameter of an axial bore through the tubular string. 58. The method of claim 55, wherein the optical sensor is configured to sense a pressure, a temperature, or a fluid composition. 59. The method of claim 55, wherein the optical sensor is configured to sense a seismic pressure wave. 60. The method of claim 55, wherein the optical sensor is configured to sense the position of the valve member. 61. The method of claim 55, wherein the DDV further comprises a receiver configured to detect a signal from a tool disposed in the drill string. 62. The method of claim 61, wherein the signal is an electromagnetic wave. 63. The method of claim 61, further comprising: receiving the signal from the tool with the receiver; and transmitting data from the DDV to the surface. 64. The method of claim 63, further comprising providing a monitoring/control unit (SMCU) at the surface of the wellbore, the SMCU in communication with the DDV. 65. The method of claim 64, wherein disposing the DDV within the tubular string comprises disposing a control line along the tubular string to provide communication between the DDV and the SMCU. 66. The method of claim 63, further comprising relaying the signal to a circuit operatively connected to the receiver. 67. The method of claim 63, wherein the tool is a measurement while drilling tool. 68. The method of claim 63, wherein the tool is a pressure while drilling tool. 69. The method of claim 63, wherein the tool is an expansion tool. 70. The method of claim 69, further comprising controlling an operation of the expansion tool based on the signal. 71. The method of claim 69, further comprising: measuring in real time a fluid pressure within the expansion tool and a fluid pressure around the expansion tool during an installation of an expandable sand screen; and adjusting the fluid pressure within the expansion tool. 72. The method of claim 55, wherein the DDV further comprises a second optical sensor, and the optical sensors are configured to sense pressure differential across the DDV. 73. The method of claim 72, wherein: the method further comprises: closing the valve member to substantially seal the first portion of the bore from the second portion of the bore; measuring the pressure differential across the DDV; equalizing a pressure differential between the first portion of the wellbore and the second portion of the wellbore; and opening the valve member. 74. The method of claim 73, wherein the first portion of the wellbore is in communication with a surface of the wellbore. 75. The method of claim 73, further comprising: providing a monitoring/control unit (SMCU) at the surface of the wellbore, the SMCU in communication with the DDV, wherein disposing the DDV within the tubular string comprises disposing a control line along the tubular string to provide communication between the DDV and the SMCU. 76. The method of claim 75, further comprising controlling a pressure in the first portion of the wellbore with the SMCU. 77. The method of claim 73, further comprising lowering the pressure in the first portion of the wellbore to substantially atmospheric pressure. 78. The method of claim 73, wherein: the DDV further comprises a third optical sensor, the third optical sensor is configured to sense the DDV position, and the method further comprises determining whether the valve member is in the open position, the closed position, or a position between the open position and the closed position with the third sensor. 79. The method of claim 73, wherein: the DDV further comprises a third optical sensor, the third optical sensor is configured to sense a temperature of the wellbore, end the method further comprises determining a temperature at the downhole deployment valve with the third sensor. 80. The method of claim 73, wherein: the DDV further comprises a third sensor, the third sensor is configured to sense the presence of the drill string, and the method further comprises determining a presence of the drill string within the DDV bore with the third sensor. 81. The method of claim 55, wherein the DDV further comprises a second sensor and the second sensor is configured to sense a presence of a drill string within the DDV. 82. The method of claim 55, wherein the DDV is located at a depth of at least ninety feet in the wellbore. 83. The method of claim 55, wherein the optical sensor is configured to sense the parameter of the wellbore or the parameter of the formation and the method further comprises sensing the wellbore or formation parameter with the optical sensor while drilling the wellbore to the second depth. 84. The method of claim 83, further comprising adjusting a trajectory of the drill string while drilling the wellbore to the second depth. 85. The method of claim 83, further comprising adjusting a composition or amount of drilling fluid while drilling the wellbore to the second depth. 86. The method of claim 83, wherein sensing the wellbore or formation parameter with the optical sensor comprises receiving at least one acoustic wave transmitted into a formation from a seismic source. 87. The method of claim 86, wherein the seismic source transmits the at least one acoustic wave from the drill string to the optical sensor. 88. The method of claim 86, wherein the seismic source transmits the at least one acoustic wave from a surface of the wellbore to the optical sensor. 89. The method of claim 86, wherein the seismic source transmits the at least one acoustic wave from an adjacent wellbore to the optical sensor. 90. The method of claim 86, wherein the seismic source transmits the at least one acoustic wave from the drill string vibrating against the wellbore to the optical sensor. 91. The method of claim 83, wherein the wellbore or formation parameter is a microseismic measurement. 92. The method of claim 55, further comprising assembling a flow meter as part of the tubular string. 93. The method of claim 92, further comprising injecting drilling fluid through the drill string while drilling the wellbore to the second depth, wherein the drilling fluid returns from the drill bit through the tubular string. 94. The method of claim 93, the method further comprises measuring characteristics of the return fluid using the flow meter. 95. The method of claim 94, further comprising determining at least one of a volumetric phase fraction for the return fluid and flow rate of the return fluid based on the measured fluid characteristics. 96. The method of claim 95, further comprising adjusting the injection rate of the drilling fluid. 97. The method of claim 95, further comprising using the at least one of the volumetric phase fraction and the flow rate to determine formation properties while drilling the wellbore to the second depth.