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WO2025017374A1 - Unité de forage à système d'évacuation sélective de dioxyde de carbone et de fluide de forage d'hydrocarbures - Google Patents

Unité de forage à système d'évacuation sélective de dioxyde de carbone et de fluide de forage d'hydrocarbures Download PDF

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Publication number
WO2025017374A1
WO2025017374A1 PCT/IB2024/052223 IB2024052223W WO2025017374A1 WO 2025017374 A1 WO2025017374 A1 WO 2025017374A1 IB 2024052223 W IB2024052223 W IB 2024052223W WO 2025017374 A1 WO2025017374 A1 WO 2025017374A1
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WO
WIPO (PCT)
Prior art keywords
valve
sensor
mud
well
controller
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Pending
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PCT/IB2024/052223
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English (en)
Inventor
Mikkel PEDERSEN
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Noble Drilling AS
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Noble Drilling AS
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Application filed by Noble Drilling AS filed Critical Noble Drilling AS
Publication of WO2025017374A1 publication Critical patent/WO2025017374A1/fr
Pending legal-status Critical Current
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/06—Arrangements for treating drilling fluids outside the borehole
    • E21B21/063—Arrangements for treating drilling fluids outside the borehole by separating components
    • E21B21/067—Separating gases from drilling fluids
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/005—Waste disposal systems
    • E21B41/0071—Adaptation of flares, e.g. arrangements of flares in offshore installations

Definitions

  • This disclosure relates to the field of drilling wells through subsurface earthen formations. More specifically, the disclosure relates to systems for venting gas (dissolved and/or entrained) from a drilling fluid circulation system so as to enhance safety of personnel working on or about a drilling unit.
  • Well drilling through subsurface earthen formations includes, among other techniques, rotary drilling, wherein a drill bit is axially urged and rotated by equipment disposed on a drilling unit (“rig”).
  • Axial force provided by controlled release of weight of drilling tools (e.g., pipe, collars, stabilizers) suspended by the rig and rotary motion provided to the drilling tools by other equipment on the rig (e.g., a top drive) causes the drill bit to crush, shear and/or gouge the subsurface formations to lengthen the well.
  • drilling fluid drilling fluid
  • mud may be pumped from surface through a channel in the drilling tools by pumps on or proximate the rig.
  • the mud exits the drill bit through nozzles, courses or jets to cool an lubricate the bit, to lift drill cuttings to surface and to provide fluid pressure in the well to restrain fluid in the drilled formations from entering the well and to provide mechanical stability to the well until the drilling is completed.
  • Such functions of the mud, particularly lifting cuttings, take place in an annular space between the drilling tools and the drilled wellbore.
  • gases are known to include hydrocarbon gases and carbon dioxide, among other gases.
  • gases expand in volume and/or exsolve from the mud as hydrostatic pressure on the mud is reduced.
  • exsolved and/or expanded gases may be removed from the mud circulation system and vented at a safe distance from the rig. Because carbon dioxide is generally more dense than air and hydrocarbon gases are less dense than air, safe venting also requires attention to the elevation at which the gases are vented to the atmosphere to avoid safety hazards to rig personnel.
  • a mud gas venting system includes a first valve connected to a mud return line and to a hydrocarbon mud gas separator.
  • a vent of the separator is connected to a vent line having an outlet at a greater elevation than any part of a drilling rig occupied by personnel.
  • the first vent line has a hydrocarbon gas sensor and a CO2 sensor.
  • a second valve connects the mud return line and a CO2 mud gas separator.
  • a vent of the CO2 mud gas separator is connected to a first vent line having an outlet disposed at a lower elevation than any part of the drilling rig occupied by personnel.
  • the second vent line has a second hydrocarbon sensor and a CO2 sensor.
  • a controller is in signal communication with the first valve, the second valve, and the CO2 sensors. The controller opens the first valve and closes the second valve when a detected CO2 concentration drops below a selected threshold. The controller closes the first valve and opens the second valve when the detected CO2 concentration exceeds the threshold.
  • Some embodiments further comprise at least a third valve connected to the mud return line and to a second CO2 mud gas separator.
  • a vent of the second CO2 mud gas separator is connected to a third vent line having an outlet disposed at a lower elevation than any part of the drilling rig occupied by personnel.
  • the outlet of the third vent line is disposed on a side of the drilling rig opposed to a side on which the outlet of the second vent line is disposed.
  • the third vent line is in fluid communication with a third hydrocarbon gas sensor and a third CO2 sensor.
  • the third hydrocarbon gas sensor and the third CO2 sensor are in signal communication with the controller.
  • the controller is operable to open the first valve and close the third valve when a detected CO2 concentration drops below a selected threshold.
  • the controller is operable to close the first valve and open the third valve when the detected CO2 concentration exceeds the selected threshold.
  • Some embodiments further comprise a wind direction sensor in signal communication with the controller.
  • the controller is operable to open the second valve and close the third valve, or to close the second valve and open the third valve based on measurements from the wind direction sensor.
  • Some embodiments further comprise a CO2 sensor module deployed by a cable extended from a winch disposed on the drilling rig.
  • the winch is disposed on the drilling rig proximate location on the drilling rig of a personnel evacuation device.
  • the CO2 sensor module comprises a third CO2 sensor in signal communication with the controller, and wherein the controller is arranged to actuate an alarm when CO2 concentration detected by the third CO2 sensor exceeds a selected threshold.
  • the CO2 sensor module comprises a buoyancy device, and the CO2 sensor module further comprises a sensor extending below the CO2 sensor module for detecting CO2 concentration in a body of water in which the CO2 sensor module is deployed.
  • Some embodiments further comprise a spring interposed between and end of the cable and the CO2 sensor module.
  • the spring has a rate selected to keep the CO2 sensor module on the surface of a body of water in which the CO2 sensor module is deployed.
  • a method for automatically controlling fluid pressure in a well includes pumping fluid into a conduit extended into the well from surface and fluid pressure in the conduit proximate the surface is measured.
  • the fluid is returned to a top of the well through an annular space between the well and the conduit.
  • the returned fluid is pumped from a location proximate the top of the well to surface, while measuring pressure, temperature and flow rate of the returned fluid.
  • a temperature of the fluid being pumped into the conduit is adjusted such that measured temperature of the returned fluid remains at a predetermined temperature.
  • the top of the well is fluidly closed and at least one of a rate of pumping fluid into the conduit and a rate of pumping the returned fluid is adjusted in response to either or both of a change in measured pressure of the returned fluid, a change in measured flow rate of the returned fluid, wherein an influx of carbon dioxide gas into the well is circulated out of the well to surface without phase change.
  • the predetermined temperature is 30 degrees Celsius.
  • FIG. 1 shows schematically an example embodiment of a drilling unit mud circulation system according to the present disclosure, which includes an automatic well pressure control apparatus used to control influx of carbon dioxide into a well during drilling operations.
  • FIG. 2 shows schematically a control valve arrangement to divert returned drilling mud to either a hydrocarbon (HC) mud gas separator or a carbon dioxide (CO2) mud gas separator.
  • HC hydrocarbon
  • CO2 carbon dioxide
  • FIG. 3 shows schematically an example embodiment of two CO2 mud gas separators each venting to a different side of the drilling unit depending on ambient wind direction.
  • FIG. 4 shows schematically a floating CO2 sensor system deployable from a marine drilling unit.
  • FIG. 5 shows the sensor part of the system of FIG. 4 in more detail.
  • FIG. 6 shows schematically a plan view of two separate CO2 vent lines from the separators shown in FIG. 3.
  • FIG. 1 A schematic drawing of an example embodiment of a well drilling fluid (drilling “mud”, or “mud” as used herein) circulation system (“system”) used in connection with well construction in marine environments is shown in FIG. 1.
  • the system 10 shown in FIG. 1 may be associated with so called “riserless” drilling of wells below the bottom of a body of water such as a lake or the ocean, however it is to be clearly understood that the present disclosure is not limited in scope to use with marine drilling systems, or drilling wells below the water bottom.
  • the system 10 comprises one or more mud pumps 12 that lift the mud from storage in a tank or pit (not shown) and discharge the mud through a standpipe system that may comprise a mud heater 13, a mud cooler 15, a pressure sensor 19 and temperature sensor 17 all of which may be in signal communication with a controller 32.
  • a standpipe system that may comprise a mud heater 13, a mud cooler 15, a pressure sensor 19 and temperature sensor 17 all of which may be in signal communication with a controller 32.
  • “Mud” as that term is used in this disclosure is intended to mean any fluid used in connection with well construction; it will be appreciated that apparatus and methods described herein may be used in connection with drilling a well through subsurface earthen formations, wherein the fluid used has composition and rheological properties understood by those skilled in the art associated with the term “mud.” Accordingly, the scope of the present disclosure is not limited to use with drilling mud.
  • the controller 32 may be implemented using any known circuitry (e.g., drivers, relays, solid state switches) for operating, e.g., the mud pump 12, the mud heater 13 and the mud cooler 15 in response to signals from the pressure sensor 19 and the temperature sensor 17, among other devices.
  • the controller 32 may be implemented, for example and without limitation, as a microcomputer, microprocessor, field programmable gate array, programmable logic controller or application specific integrated circuit.
  • the implementation of the controller 32 is not a limit on the scope of the present disclosure; the functions ascribed to the controller 32 in this disclosure could equally be implemented with analog control devices.
  • control functions attributed to the controller 32 in this disclosure may in some embodiments be implemented on separate, discrete devices; reference to “the controller” herein is meant as shorthand to include any combination of a single, central control device or a plurality of separate control devices. Accordingly, the scope of this disclosure is not limited to a single device performing the functions attributed herein to the controller 32.
  • Drilling mud may be pumped through a standpipe system (not shown separately) and then into drilling tools in a well 18.
  • the mud leaving the standpipe system may be discharged through a top drive 14, which suspends and rotates a drilling tool string 16 in order to drill and perform certain other functions on or in a well 18 drilled through subsurface formations 18A, in the present example below the bottom of a body of water (not shown for clarity).
  • Drilling mud pumped into the well 18 may be urged to return to the surface through a pressure control apparatus 25 connected to the upper end of a well casing (not shown for clarity).
  • the pressure control apparatus 25 serves to close an annular space 16A between the drilling tool string 16 and the well 18 in the event of inadvertent influx of fluids from the formations 18A, and to divert flow of the returning mud into a subsea mudlift system, explained further below.
  • the pressure control apparatus 25 may comprise electrically and/or hydraulically operated rams, such as a blind ram 26 and pipe ram (and/or shear ram) 24 disposed below an annular closure element 22.
  • a rotating control device (RCD) 20 of types well known in the art may enable longitudinal passage and movement of the drilling tool string 16 while maintaining a fluid tight seal to close the top of the annular space.
  • a mud return line 29 may connect discharge from the annular space 16A below the RCD 20 to the inlet of a subsea mudlift (SMD) pump 27.
  • SMD subsea mudlift
  • Pressure and temperature of the mud entering the SMD pump 27 inlet may be measured by respective sensors 28, 30.
  • Flow rate of the returning mud into the SMD pump 27 inlet may be measured by a flowmeter 31, such as a Coriolis flowmeter.
  • Mud is discharged from the SMD pump 27 into a mud return line 34A which extends to the surface, where it may then be connected to a mud return flowline 34 for further processing on the surface (e.g., on the drilling rig) to be explained further below.
  • certain features of the mud circulation system shown in FIG. 1 are related to marine riserless drilling.
  • the present disclosure is not limited to use in such drilling.
  • certain components of the circulation system may be located at the surface, e.g., the pressure control apparatus 25, the RCD 20, the annular closure element 22, the SMD pump (in which case it may be referred to as a mud return pump) 27 and its associated sensors 28, 30 and the flowmeter 31.
  • the return line 34A would effectively be eliminated; discharge from below the RCD 22 would be directed to the flow line 34.
  • FIG. 2 shows schematically part of a mud gas separating and venting system according to the present disclosure.
  • Mud returning through the return flowline 34 may pass through a variable orifice flow control (“choke”) 36 so that a suitable fluid pressure may be maintained in the mud returning to the surface from the SMD pump (27 in FIG. 1).
  • the choke 36 may be operated by an electrical or hydraulic actuator so as to be controllable by the controller (32 in FIG. 1). Mud leaving the choke 36 may be directed to two valves 38 and 40, which may also be operated by the controller (32 in FIG. 1).
  • One of the valves, at 38, and which may be referred to as a hydrocarbon mud gas separator inlet valve, may open to direct mud flow to a hydrocarbon mud gas separator 42, wherein hydrocarbon gases entrained in and dissolved in the mud may be extracted and vented, e.g., to a mud gas separator vent line having an outlet located at the top of the derrick in the drilling rig as will be explained with reference to FIG. 6.
  • the exact location of the outlet (not shown in FIG. 2) is not a limitation on the present disclosure; it is advisable to have the outlet located at greater elevation than any part of the drilling rig that will be occupied by personnel.
  • Discharge from the hydrocarbon mud gas separator 42 may be subject to measurement by a hydrocarbon and CO2 gas sensor 39, which is in signal communication with the controller (32 in FIG. 1 and FIG. 3). Use of measurements from such sensor 39 will be further explained with reference to FIG. 3.
  • the other valve 40 which may be referred to as the CO2 mud gas separator inlet valve, may also be operated by the controller (32 in FIG. 1) and opened to direct the returning mud flow to a CO2 mud gas separator system, to be explained with reference to FIG. 3.
  • the controller (32 in FIG. 1) may be programmed or otherwise arranged such that closing the one valve 38 does not take place until the other valve 40 is opened, to avoid inadvertent pressure build up in the mud return flowline 34.
  • FIG. 3 shows other parts of the mud gas separation system that may be disposed on or near the drilling unit.
  • mud leaving the CO2 mud gas separator inlet valve (40 in FIG. 2) may be directed to CO2 mud gas separation equipment.
  • Such equipment may comprise, in the present example embodiment, a first (e.g., port side) CO2 separator valve 45.
  • the first CO2 separator valve 45 may be hydraulically or electrically operated by the controller 32 and when opened may direct flow to, e.g., a port side CO2 mud gas separator 44.
  • Port side are only descriptive terms used in connection with a frame of reference on the drilling unit, and such terms are not limitations on the scope of the present disclosure or an indication that a particular geodetic or other directional reference is required to make and use a system according to the present disclosure.
  • Mud passing through the port side CO2 mud gas separator 44 may have the liquid portion directed to further processing devices such as screens, shale shakers and the like, which are well known in the art for removing drill cuttings and other solids from the returned mud.
  • Gas extracted by the port side CO2 mud gas separator 44 may enter a port side vent line 44A for ultimate venting at the end of such line to the atmosphere. The manner and location of the end of the port side vent line 44A will be further explained with reference to FIG. 6.
  • Returned mud may in the alternative be directed to a second (e.g., starboard side) CO2 separator valve 47.
  • the second CO2 separator valve 47 may be operated electrically or hydraulically by the controller 32 as will be explained further below.
  • returned mud may flow to a starboard side CO2 mud gas separator 46.
  • the starboard side CO2 mud gas separator 46 may be similar in structure to the port side CO2 mud gas separator 44. Gas discharge from the starboard side CO2 mud gas separator 46 may be directed to a starboard side vent line 46A.
  • Each of the port side vent line 44A and the starboard side vent line 46A may comprise a CO2 gas sensor and a hydrocarbon gas sensor, shown collectively at 48. Such sensors 48 may be in signal communication with the controller 32.
  • a CO2 gas sensor is sold under model number GDlOP-CCh by Teledyne Gas and Flame Detection, 14880 Skinner Rd, Cypress, Texas 77429.
  • An example of a hydrocarbon gas sensor is sold under model number GDI OP, also by Teledyne Gas and Flame Detection.
  • a wind speed and direction sensor 41 may be disposed at any suitable location on or near the drilling rig, and such sensor may be in signal communication with the controller 32.
  • signals from the hydrocarbon (HC)/CO2 sensors 48 are communicated to the controller 32, in which is determine from the signals the concentration of CO2 and/or hydrocarbon gases in the discharge from the port and starboard side CO2 mud gas separators 44, 46, respectively. Wind speed and direction signals from the respective sensor 41 are also entered into the controller 32. If signals from the respective hydrocarbon/CO2 sensors 39, 48 indicate that gases in the returned mud comprise hydrocarbons above a predetermined threshold concentration, the controller 32 may operate the hydrocarbon mud gas separator inlet valve (38 in FIG. 2) to open flow to the hydrocarbon mud gas separator (42 in FIG. 2) and operate the CO2 mud gas separator inlet valve (40 in FIG. 2) to stop flow to the CO2 system inlet (valves 45 and 47 in FIG. 3). Separated hydrocarbon gases will be directed to the mud gas separator vent line as explained with reference to FIG. 2.
  • the controller 32 may operate the hydrocarbon mud gas separator inlet valve (38 in FIG. 2) to stop flow to the hydrocarbon mud gas separator (42 in FIG. 2) and operate the CO2 mud gas separator inlet valve 40 to enable flow to the system components in FIG. 3.
  • the controller 32 operates either the port side CO2 separator valve 45 or the starboard side CO2 separator valve 47 to open flow to the respective CO2 mud gas separator, 44 or 46, based on ambient wind speed and direction detected by the respective sensor 41, such that vented CO2 from the respective vent line 44A, 46A will be directed to a location downwind of the drilling rig. In this way risk of personnel exposure to vented CO2 is reduced.
  • each of the CO2 mud gas separators shown in FIG. 3 is illustrate as having a respective inlet valve at 45 and 47. It is within the scope of the present disclosure for the system to omit the CO2 gas separator inlet valve shown at 40 in FIG. 2, wherein the mud return line (34 in FIG. 1) is directly connected to the valves shown at 45 and 47 in FIG. 3.
  • FIGS. 4 and 5 show an example embodiment of a floating CO2 sensor module that may be used in connection with evacuation safety procedures in the event it becomes necessary to evacuate the drilling rig during well operations where CO2 is being vented.
  • the sensor module 60 may be disposed in an enclosure 70 on the drilling rig.
  • the sensor module 60 comprises a buoyant sensor housing 62 to be explained in more detail with reference to FIG. 5.
  • the buoyant sensor housing 62 may be coupled on its upper end to one end of a compensator spring 68.
  • the compensator spring 68 may be connected at its other end to a deployment cable 66, which may be an armored electrical cable having one or more insulated electrical conductors to act as a power and/or signal transmission channel.
  • the deployment cable 66 may be spooled on a winch or drum 64.
  • the winch or drum 64 may be configured to extend a selected length, e.g., based on an elevation of the sensor module 60 above water level when used on a marine drilling platform.
  • the selected length may be chosen such that the fully extended length of the deployment cable 66 is 3 to 5 meters above water level.
  • the remaining distance to the water may be traversed by weight of the sensor housing 62 extending the compensator spring 68.
  • the sensor housing 62 may remain on the water surface.
  • the sensor housing 62 may be retained in the enclosure 70, for example, by a solenoid operated release latch or cylinder 72.
  • the release latch 72 and the sensor housing 62 may be in signal communication with the controller 32.
  • An alarm such as a warning siren or horn 74 may also be in signal communication with the controller 32.
  • the sensor housing 62 may comprise a CO2 sensor 61, such as the Teledyne GD10P-CO2 sensor explained with reference to FIG. 3 to detect presence of CO2 gas in the ambient air near the water surface.
  • a dissolved CO2 gas sensor e.g., a pH sensor 63 may be in contact with the water near the surface to detect presence of CO2 in the water, e.g., as may be caused by being proximate a subsurface reservoir that has high concentrations of CO2 in fluids in such reservoir.
  • the CO2 sensor 61 may be disposed within a container 62A arranged to limit entry of water into the container 62A while enabling free flow of ambient air therethrough.
  • the enclosure 60 will be located on the drilling rig proximate a location where escape devices are stored for deployment in the event it becomes necessary to evacuate the drilling rig.
  • the sensor module 62 When the release latch 72 is activated, the sensor module 62 will start descending to the water surface by gravity.
  • the CO2 sensor will the start measuring CO2 in the atmosphere just above sea level, and using the dissolved CO2 sensor 61, detecting any decrease in the pH value of the seawater.
  • the controller 32 will transmit a signal to the drilling rig, and activate the alarm signal and horn 74.
  • the disclosed mud circulation system 10 and associated components of the drilling rig may advantageously automatically detect, close the well hydraulically and circulate out influxes of CO2 gas into the mud.
  • Time can be critical in the event of an influx of CO2 (a “kick”) into the well 18. It is therefore desirable to have an automated system that can close in the well in due time. To close the well promptly in the event of a kick, the circulation system 10 needs to be able to detect a fluid influx as early as possible.
  • the riserless mud return system enables detecting a pressure increase and increased flow to the mud return pump, in case of an influx to the well, by measurements made from the pressure sensor 28 and flowmeter 31.
  • the annular closure element 22 may be an electrically operated annular blowout preventer that is capable of closing in less than 10 seconds.
  • the automated CO2 well control system shall automatically perform all related actions (stop the mud pump 12, stop drawworks movement, stop top drive 14 rotation and close the annular closure element 22) using best practice for closing in a well, within 30 sec.
  • the temperature may be maintained to within a predetermined tolerance of 30 degrees C.
  • the foregoing may be performed by measuring the mud temperature going into the well (e.g., at 17) and mud return temperature (e.g., at 30) and operate as needed the heater 13 or cooler 15 on the standpipe system (explained above) that can heat or cool the mud entering the well 18 until the return temperature is within a predetermined variance from a setpoint temperature (e.g., 30° C in the above example). This is to reduce the risk of a phase change of the CO2 in the well.
  • CO2 kicks are difficult to detect due to the low density of the gas, which as a result gives a very little change in the mud weight (density, expressed in pounds per gallon), and also is hard to detect using mud level gauges in the mud pit system.
  • the controller 32 starts automatically to shut in the well 18, by sending signals to: the drawworks to space out the drill string; the top drive 14 to stop rotation, and release torque; the mud pump 12 to ramp down; and the pressure control apparatus 25 to close at least the annular closure element 22.
  • FIG. 6 shows a plan view of an example embodiment of a drilling rig 80 that may use equipment and methods according to the present disclosure.
  • the drilling rig 80 may be, for example and without limitation a bottom-supported mobile offshore drilling unit (MODU) known as a “jack up” rig.
  • MODU mobile offshore drilling unit
  • Possible locations on the drilling rig 80 for the port side CO2 mud gas separator 44 and its associated discharge line 44A, and the starboard side CO2 mud gas separator 46 and its associated discharge line 46A are shown in FIG. 6.
  • the port side vent line 44A may be connected to a venting line 81 having an outlet 82A disposed proximate the water surface and at a selected distance away from the drilling rig 80 such that vented CO2 gas may have adequate possibility to disperse to safe concentrations for personnel on the drilling rig 80 and any approaching service vessels.
  • the starboard side vent line 46A may comprise a corresponding venting line 84 having an outlet 84A disposed a similar distance from the drilling rig 80 and in opposed direction than the port side venting line 82A, whereby the controller (32 in FIG. 3) selects the one of the port side or starboard side mud gas separators (explained with reference to FIG.

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  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
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  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
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Abstract

Un système d'évacuation de gaz-boue comprend une première vanne reliée à une conduite de retour de boue et à un séparateur gaz-boue d'hydrocarbures. Un évent du séparateur est relié à une conduite d'évent ayant une sortie à une élévation supérieure à celle de toute partie de l'appareil de forage occupée par le personnel. La conduite d'évacuation comprend un capteur d'hydrocarbures et un capteur de CO2. Une seconde vanne relie la conduite de retour et un séparateur gaz-boue de CO2. Un évent du séparateur gaz-boue de CO2 est relié à une conduite d'évent ayant une sortie disposée à une hauteur inférieure à celle de toute partie de l'appareil de forage occupée par le personnel. La conduite d'évacuation comprend un second capteur d'hydrocarbures et un capteur de CO2. Un dispositif de commande est en communication avec la première vanne, la seconde vanne et les capteurs de CO2. Le dispositif de commande ouvre la première vanne et ferme la seconde vanne lorsque la concentration en CO2 tombe au-dessous d'un seuil. Le dispositif de commande ferme la première vanne et ouvre la seconde vanne lorsque la concentration en CO2 dépasse le seuil.
PCT/IB2024/052223 2023-07-14 2024-03-07 Unité de forage à système d'évacuation sélective de dioxyde de carbone et de fluide de forage d'hydrocarbures Pending WO2025017374A1 (fr)

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US202363513691P 2023-07-14 2023-07-14
US63/513,691 2023-07-14

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Citations (6)

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Publication number Priority date Publication date Assignee Title
US2923151A (en) * 1956-12-17 1960-02-02 Phillips Petroleum Co Extracting and analyzing gas from well drilling mud
US3498393A (en) * 1967-09-26 1970-03-03 W & H Production Drilling Inc Well control method
CN102606069A (zh) * 2012-04-01 2012-07-25 中国石油大学(华东) 超临界二氧化碳钻井井筒内相态的控制装置
WO2019060098A1 (fr) * 2017-09-19 2019-03-28 M-I L.L.C. Dégazage et analyse de fluide de forage
CN111894520A (zh) * 2019-05-06 2020-11-06 中石化石油工程技术服务有限公司 一种基于石蜡材料调控钻井液温度的方法
CN115112845A (zh) * 2022-08-23 2022-09-27 中石化胜利石油工程有限公司钻井工艺研究院 一种用于检测油基钻井液性能的系统及方法

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2923151A (en) * 1956-12-17 1960-02-02 Phillips Petroleum Co Extracting and analyzing gas from well drilling mud
US3498393A (en) * 1967-09-26 1970-03-03 W & H Production Drilling Inc Well control method
CN102606069A (zh) * 2012-04-01 2012-07-25 中国石油大学(华东) 超临界二氧化碳钻井井筒内相态的控制装置
WO2019060098A1 (fr) * 2017-09-19 2019-03-28 M-I L.L.C. Dégazage et analyse de fluide de forage
CN111894520A (zh) * 2019-05-06 2020-11-06 中石化石油工程技术服务有限公司 一种基于石蜡材料调控钻井液温度的方法
CN115112845A (zh) * 2022-08-23 2022-09-27 中石化胜利石油工程有限公司钻井工艺研究院 一种用于检测油基钻井液性能的系统及方法

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