Abstract: Systems and methods for managed pressure cementing and/or completions operations in subterranean well bores are provided. In some embodiments, the methods comprise: placing a tubular string into a well bore, wherein an outer surface of the tubular string and an inner wall of the well bore define an annulus in a closed pressure loop and in communication with a choke valve; pumping a fluid into the annulus; and while pumping the fluid, determining a setpoint for the choke valve corresponding to a setpoint for a bottomhole pressure in the annulus, determine an actual bottomhole pressure in the annulus using data from a downhole sensor in the annulus, determining if the actual bottomhole pressure is greater than, less than, or equal to the setpoint, and if the actual bottomhole pressure is greater or less than the setpoint, manipulating the choke valve using a controller to decrease or increase the bottomhole pressure.

Abstract: Methods and systems including a wellbore having a pipe string extending through a wellhead and into the wellbore, wherein an annulus is formed between the pipe string and the wellbore, an isolation device that closes the wellbore in a closed pressure loop, a choke line in fluid communication with an interior of the pipe string through an outlet port of the wellhead, a choke valve fluidly coupled to the outlet port of the wellhead, wherein the choke valve is manipulable to control fluid flow through the choke line, and a crossover tool in the wellbore to divert incoming fluid from the interior of the pipe string to the annulus.

Abstract: Well systems and methods are provided. An example well system comprises a lubricator assembly. The lubricator assembly comprises a lubricator head. The lubricator head comprises a removable sealing cartridge, a plurality of sealing elements disposed in the sealing cartridge, and a lubricating fluid cavity disposed between two individual sealing elements of the plurality of sealing elements. The lubricator assembly further comprises a lubricator body. The lubricator body comprises a lubricator seal conduit pipe. The example well system also comprises a slip joint coupled to the lubricator seal conduit pipe and a statically underbalanced drilling fluid disposed in the lubricator seal conduit pipe.

Abstract: Systems and methods for performing positive and/or negative pressure testing in managed pressure operations in subterranean well bores are provided. In some embodiments, the methods comprise: performing a positive or negative pressure test in a well bore in a subterranean formation, wherein the well bore is maintained in a closed pressure loop, and at least one choke valve is provided in communication with the well bore, the choke valve being coupled to a controller, and during the test in the well bore, monitoring an actual bottomhole pressure in the well bore using data from at least one downhole sensor in the well bore, and if the actual bottomhole pressure in the well bore increases or decreases, manipulating the choke valve using the controller to increase or decrease the bottomhole pressure in the well bore.

Abstract: Various embodiments include apparatus and methods to generate and use drillability exponents. Data acquired from downhole sensors can be used to determine drillability exponents. The drill exponents can be used in number of processes to enhance various features of a drilling operation. 5 Additional apparatus, systems, and methods are disclosed.

Abstract: Various managed pressure drilling tools, systems, and methods are disclosed. An example method includes obtaining a model-based pressure prediction and sensor-based pressure measurements during borehole drilling operations. The method also includes determining a real-time learning calculation using the model-based pressure prediction and at least some of the sensor-based pressure measurements. The method also includes updating a formation pressure model based at least in part on the real-time learning calculation. The method also includes controlling annular pressure for the borehole drilling operations based on a pressure predicted by the updated formation pressure model.

Abstract: Methods and systems including a wellbore having a pipe string extending through a wellhead and into the wellbore, wherein an annulus is formed between the pipe string and the wellbore, an isolation device that closes the wellbore in a closed pressure loop, a choke line in fluid communication with an interior of the pipe string through an outlet port of the wellhead, a choke valve fluidly coupled to the outlet port of the wellhead, wherein the choke valve is manipulable to control fluid flow through the choke line, and a crossover tool in the wellbore to divert incoming fluid from the interior of the pipe string to the annulus.

Abstract: Disclosed embodiments include systems and methods for improving the accuracy of bottom hole pressure control. One example embodiment includes a torque and drag model that calculates the elasticity of the drill string, which is included in a managed pressure drilling control system. The addition of the torque and drag calculations provide more accurate surge/swab effect calculations based on pipe movement corrected for elasticity effects. The results of these calculations will be used in a real-time hydraulics model to determine a setpoint pressure which will be utilized by a MPD choke system. Further, the real-time torque and drag models are calibrated to actual hole conditions in real-time using survey, temperature, pressure and downhole tool data to calculate friction factors in a wellbore.

Abstract: Well systems and methods are provided. An example well system comprises a lubricator assembly. The lubricator assembly comprises a lubricator head. The lubricator head comprises a removable sealing cartridge, a plurality of sealing elements disposed in the sealing cartridge, and a lubricating fluid cavity disposed between two individual sealing elements of the plurality of sealing elements. The lubricator assembly further comprises a lubricator body. The lubricator body comprises a lubricator seal conduit pipe. The example well system also comprises a slip joint coupled to the lubricator seal conduit pipe and a statically underbalanced drilling fluid disposed in the lubricator seal conduit pipe.

Abstract: Systems and methods for performing positive and/or negative pressure testing in managed pressure operations in subterranean well bores are provided. In some embodiments, the methods comprise: performing a positive or negative pressure test in a well bore in a subterranean formation, wherein the well bore is maintained in a closed pressure loop, and at least one choke valve is provided in communication with the well bore, the choke valve being coupled to a controller, and during the test in the well bore, monitoring an actual bottomhole pressure in the well bore using data from at least one downhole sensor in the well bore, and if the actual bottomhole pressure in the well bore increases or decreases, manipulating the choke valve using the controller to increase or decrease the bottomhole pressure in the well bore.

Abstract: Systems and methods for managed pressure cementing and/or completions operations in subterranean well bores are provided. In some embodiments, the methods comprise: placing a tubular string into a well bore, wherein an outer surface of the tubular string and an inner wall of the well bore define an annulus in a closed pressure loop and in communication with a choke valve; pumping a fluid into the annulus; and while pumping the fluid, determining a setpoint for the choke valve corresponding to a setpoint for a bottomhole pressure in the annulus, determine an actual bottomhole pressure in the annulus using data from a downhole sensor in the annulus, determining if the actual bottomhole pressure is greater than, less than, or equal to the setpoint, and if the actual bottomhole pressure is greater or less than the setpoint, manipulating the choke valve using a controller to decrease or increase the bottomhole pressure.

Abstract: A fluid monitoring system comprises a data acquisition and control interface and one or more fluid measurement devices communicatively coupled to the data acquisition and control interface. The one or more fluid measurement devices are configured to detect amounts of fluids pumped into or exiting the well bore during cementing. The data acquisition and control interface receives a first set of data comprising calculated volumes and/or pressures of a flow of one or more fluids exiting a model well bore over a predetermined period of time based in part on a heat of reaction produced by the curing of a cement composition, and a second set of data comprising volumes and/or pressures of a flow of one or more fluids pumped into or exiting the well bore from the one or more fluid measurement devices. The data acquisition and control interface uses the first and second sets of data received to determine one or more characteristics of the cement composition.

Abstract: A method of controlling the equivalent circulating density of an epoxy resin, used to cement a wellbore, the method includes introducing an epoxy resin into an annulus defined by a casing string and an inner wall of the wellbore. Backpressure is asserted on the epoxy resin as it flows through the annulus. Some embodiments include adjusting the cross sectional area of the annulus exit using a valve or other mechanism to control the backpressure and thus increase or decrease the equivalent circulating density of the epoxy resin.

Abstract: A drilling system includes a string of drill pipe extending into a wellbore from a drilling platform. A Y-block junction is coupled to the string of drill pipe at the drilling platform and provides a pressure housing that defines a first conduit and a second conduit that converges with the first conduit. The pressure housing further defines an outlet configured to be coupled to the string of drill pipe extending into the wellbore. A lubricator is operatively coupled to the Y-block junction at the second conduit, and a cable having one or more optical fibers embedded therein is conveyed into the wellbore within the string of drill pipe via the lubricator and the Y-block junction.

Abstract: A method of controlling the equivalent circulating density of an epoxy resin, used to cement a wellbore, is provided. The method includes adjusting the cross sectional area of the annulus exit using a valve or other mechanism to increase or decrease the equivalent circulating density of the epoxy resin.

Abstract: The present disclosure provides systems and methods for expanded mud pulse telemetry. Certain methods provided include measuring pressure proximate at least one of first and second pressure control modules along a drilling apparatus and telemetering the measured pressure to a surface controller. A command is transmitted from the surface controller to at least one of the first and second pressure control modules or one of first and second controllable flow restrictors via mud pulse telemetry while mud is not being pumped through a main standpipe.

Abstract: A method of regulating downhole pressure using managed pressure drilling may include calculating an elasticity of a drill string during a drilling operation using a torque and drag model included in a managed pressure drilling (MPD) control system and calculating a surge pressure and a swab pressure acting on the drill string during the drilling operation using a hydraulics model included in the MPD control system. The surge and swab pressures may be based on movement of the drill string and in accordance with the elasticity of the drill string. The method may further include determining a set point pressure using a real-time hydraulics model and the torque and drag model, and operating a MPD choke system based on the set point pressure to regulate a predetermined downhole pressure at a predetermined location in a wellbore.

Abstract: Various embodiments include apparatus and methods to generate and use drillability exponents. Data acquired from downhole sensors can be used to determine drillability exponents. The drill exponents can be used in number of processes to enhance various features of a drilling operation. 5 Additional apparatus, systems, and methods are disclosed.

Abstract: Disclosed embodiments include systems and methods for improving the accuracy of bottom hole pressure control. One example embodiment includes a torque and drag model that calculates the elasticity of the drill string, which is included in a managed pressure drilling control system. The addition of the torque and drag calculations provide more accurate surge/swab effect calculations based on pipe movement corrected for elasticity effects. The results of these calculations will be used in a real-time hydraulics model to determine a setpoint pressure which will be utilized by a MPD choke system. Further, the real-time torque and drag models are calibrated to actual hole conditions in real-time using survey, temperature, pressure and downhole tool data to calculate friction factors in a wellbore.

Abstract: Various managed pressure drilling tools, systems, and methods are disclosed. An example method includes obtaining a model-based pressure prediction and sensor-based pressure measurements during borehole drilling operations. The method also includes determining a real-time learning calculation using the model-based pressure prediction and at least some of the sensor-based pressure measurements. The method also includes updating a formation pressure model based at least in part on the real-time learning calculation. The method also includes controlling annular pressure for the borehole drilling operations based on a pressure predicted by the updated formation pressure model.