• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    SYSTEM, AND METHOD A system and method includes pumping drilling fluid through a drilling column extended into a well, extending below the bottom of a body of water, exiting through the bottom of the drilling column and into space annul the well. Fluid is discharged from the annular space into a riser and a discharge duct. The ascent conductor is placed above the top of the well and extends to the water surface. The discharge line is coupled to the riser and includes a controllable fluid regulator. A fluid return line is coupled to a regulator outlet and extends to the water surface. Pressure gas is pumped into the return line at a selected depth below the water surface. The controllable fluid regulator can be operated in order to maintain a selected drilling fluid level in the rising conductor, the selected fluid level being at a selected distance below the water surface.
    公开号:BR112014026864B1
    申请号:R112014026864-9
    申请日:2013-04-29
    公开日:2020-12-08
    发明作者:Donald G. Reitsma；Ossama R. Sehsah；Yawan Couturier
    申请人:Schlumberger Technology B.V；
    IPC主号:
    专利说明:

    FUNDAMENTALS
    [0001] The exploration and production of hydrocarbons from underground formations includes systems and methods for extracting hydrocarbons from the formation. A drill rig can be positioned on dry land or in a body of water to support a drill string extended downwards, inside a well. The drill string may include a downhole assembly consisting of a drill bit and sensors, as well as a telemetry system, capable of receiving and transmitting sensor data. Sensors arranged in the downhole assembly may include pressure and temperature sensors. A surface telemetry system is included to receive telemetry data from the downhole assembly sensors and to transmit commands and data to the downhole assembly.
    [0002] Fluid "drilling mud" is pumped, from the drilling platform, through the drilling column, to a drilling bit, supported on the lower or distal end of the drilling column. The drilling mud lubricates the drill bit and drags away well cuts generated by the drill bit as it deepens. The cuts are dragged in a flow stream of drilling mud return, through the annular space of the well, and return to the well drilling platform, on the surface of the earth. When the drilling mud reaches the platform, it is contaminated with small pieces of gravel and rock, which are known in the industry as well cuts or drilling cuts. Once drilling cuts, drilling mud and other debris reach the platform, separation equipment is used to remove the drilling cuts from the drilling mud so that the drilling mud can be reused.
    [0003] A fluid back pressure system can be connected to a fluid discharge duct, to selectively control the fluid discharge, in order to maintain a selected pressure at the bottom of the borehole. The fluid can be pumped under the drilling fluid return system to maintain the pressure of the annular space during periods when the mud pumps are off. A pressure monitoring system can also be used to monitor detected borehole pressures, well pressures predicted by model for subsequent drilling, and to control the fluid back pressure system. BRIEF DESCRIPTION OF THE DRAWINGS
    [0004] FIG. 1 shows a drilling system, including an example of a pressure controlled drilling system.
    [0005] FIG. 2 shows an example of a pressure controlled drilling system, as in FIG. 1, used in connection with a drilling fluid return line carrying a gas-raised drilling fluid, in accordance with embodiments disclosed in this document.
    [0006] Figs. 3 to 5 show examples of pressure controlled drilling systems used, according to embodiments disclosed in this document. DETAILED DESCRIPTION
    [0007] Embodiments disclosed in this document refer to a system that includes, according to one aspect, a drilling column extended inside a well below a bottom of a body of water, a primary pump for pumping, selectively, a drilling fluid, through the drilling column, and into an annular space created between the drilling column and the well, a riser extending from an upper part of the well to a platform on the surface of the water body, a fluid discharge duct in fluid communication with the riser, a controllable orifice regulator coupled to the discharge duct, a fluid return line extended from the regulator to the platform, and a source of compressed gas coupled to the fluid return line, at a selected depth below the surface of the water body.
    [0008] In some embodiments, a pressure sensor can be coupled to a discharge duct close to the regulator and / or to a selected depth in the well, or in the riser. The system can also include a controller, which receives an input signal from the pressure sensor and generates an output signal to operate the regulator. The regulator is operated to maintain a selected hydrostatic pressure in the rising conductor, at a selected distance below the water surface.
    [0009] According to certain embodiments described here, a system, as described, can be used to control the pressure of the annular space of the well during the drilling of an underground marine formation, that is, a formation disposed below a mass of water. Embodiments disclosed herein may also relate to a method for controlling the pressure of the annular space of the well, while drilling an underground marine formation.
    [00010] In one aspect, a method, according to embodiments disclosed herein, includes pumping drilling fluid through a drilling column extended into a well, extended below the bottom of a body of water, out of the bottom of the drilling column, and into the annular space of the well, discharge fluid from the annular space of the well and into a rising conductor arranged above the top of the well, the rising conductor extended to the surface of the water body , discharge fluid from the riser into a discharge duct located below the surface of the water body, the discharge duct, including, inside, a controllable fluid regulator, a fluid return line coupled to an outlet from the regulator, and extended to the surface of the water body, pump gas under pressure into the return line, at a selected depth below the surface of the water body, and operate the fluid regulator controllable to maintain a selected hydrostatic pressure in the rising conductor, at a selected distance below the surface of the water body.
    [00011] In another aspect, a method, according to embodiments disclosed herein, includes pumping drilling fluid, through a drilling column extended into a well extended below the bottom of a body of water, leaving the bottom of the drilling column, and into the annular space of the well, discharge fluid from the annular space of the well into a rising conductor above the top of the well and into a discharge duct, the discharge duct including a fluid regulator and a fluid return line coupled to a fluid regulator outlet and extended to the water surface, pump gas under pressure into the return line, at a selected depth below the water surface, and control a flow, in which the gas is pumped into the return line to maintain a fluid level in the rising conductor, at a selected distance below the surface of the water body.
    [00012] A drilling system, including an example of pressure-controlled drilling, is shown schematically in FIG. 1. An example of a pressure controlled drilling system is a dynamic ring pressure control system (DAPC), as described in U.S. Patent No. 6,904,981, granted to Van Riet and incorporated in its entirety by reference in that document. A drilling unit ("rig") 14, or similar lifting device, suspends a drilling column 10 in a well 11, being drilled through underground rock formations 13. A drilling bit 12 is attached to the lower end of the drilling column. drilling 10, and is rotated by drilling column 10. The rotatable drilling column can be activated by a hydraulic motor or by a turbine (not shown) coupled to drilling column 10, or by equipment, such as a top driver16, in suspension on the drill rig 14. The application of part of the weight of the drill string 10 to drill 12, and the rotation transmitted to drill 12, causes drill 12 to drill into formations 13, thereby increasing the length of well 11 The drilling unit 14 is shown resting on the surface of the earth 13A; however, the drilling unit 14, including part or all of the components described in FIG. 1, can be used in marine drilling and can be placed on a platform on the water surface. This will be explained below, with reference to FIG. two.
    [00013] In the embodiment shown in FIG. 1, a primary pump ("mud pumps") 26, on the surface of the earth, lifts the drilling fluid ("mud") 34 from a tank or pit 24 and discharges the mud 34 under pressure through a cane tube and a flexible hose 31, to the top drive 16. The top drive 16 includes internal rotary seals, to allow mud 34 to move through the top drive 16, to an inner duct (not shown) inside the drill string 10 The drill string 10 can include a check valve 22, or a similar device, to prevent reverse movement of the mud 34, during periods when the mud pumps 26 are not activated, and / or when the top drive 16 is disconnected from the top end of the drill string 10, for example, during "connections" (add or remove pipe segments from the drill string 10).
    [00014] As mud 34 advances through drill column 10, it is finally discharged through the nozzles or fluid strokes (not shown separately) on drill bit 12. After leaving drill bit 12, mud 34 enters the annular space, between the exterior of the drilling column 10 and the wall of the well 11. The mud 34 raises the drilling cuts of the well 11, as it returns to the surface of the earth 13A.
    [00015] The discharge of mud 34 from the annular space can be controlled by a back pressure system. The back pressure system may include the rotary control head (or rotary safety valve) 18, coupled to the top end of a surface liner or tube 19. The rotary control head 18 seals against the drill string 10, thereby preventing Thus, the discharge of fluid from the well, except through a discharge line 20. The liner 19 is generally cemented inside the upper part of the well 11. Mud 34 leaves the annular space, through the discharge line 20. The line discharge 20 can be coupled to one end of the rotating control head 18 and coupled, at its other end, to a discharge line regulator, that is, a controllable orifice regulator 30, which selectively controls the pressure, at which sludge 34 exits the discharge line 20. After exiting the discharge line regulator 30, sludge 34 can be discharged into cleaning devices, shown collectively at 32, as a degasser to remove air gas from mud 34, and / or a "mud sieve" to remove solid particles from mud 34. After leaving cleaning devices 32, mud 34 returns to reservoir 24. The operation of regulator 30 can be related to measurements made by a pressure sensor 28 in hydraulic communication with the discharge line 20.
    [00016] The back pressure system can also include a back pressure pump 42, which can lift the mud from the tank 24. The back pressure pump 42 may be smaller, in relation to the pumping capacity, than the primary pump 26. The side discharge valve of the back pressure pump 42 can be hydraulically coupled to an accumulator 36. A non-return valve 39 can be included in the previous connection, to prevent the slurry under pressure in the accumulator 36 from flowing back through the back pressure pump 42 by example, when the back pressure pump 42 is not activated. A pressure sensor 40 can be included in the previous connection to automatically shut off the back pressure pump 42, when the accumulator 36 is charged to a predetermined pressure. The accumulator 36 is also connected hydraulically to the discharge line 20, through a controllable orifice regulator, for example, accumulator regulator 38 (which can be replaced by, or include, a valve).
    [00017] During the operation of this back pressure system, the back pressure pump 42 operates to charge the accumulator 36. As the fluid volume is necessary to maintain the back pressure in the discharge line 20, the accumulator regulator 38 can be operated to allow the flow from the accumulator 36 to the discharge line 20. At the same time, the discharge line regulator 30 can be operated to interrupt, substantially or completely, the mud flow 34.
    [00018] In other examples, the back pressure pump 42 can be omitted, and part of the discharge from the mud pump 26 can be used to charge the accumulator. An example is shown by the dotted line 43 in FIG. 1, which indicates the fluid coupling of part of the fluid emitted from the mud pump 26 to the accumulator 36.
    [00019] The accumulator 36 can be any type known in the art, for example, types having a movable seal, diaphragm or piston to separate the accumulator 36 in two pressure chambers. Some accumulators may have the diaphragm or piston side opposite the side charged with pre-pressurized fluid at a selected pressure, as with compressed gas and / or a spring or other thrust device, to provide a selected force for the diaphragm or piston. In other accumulators, the opposite side of accumulator 36 can be charged with fluid under pressure using a separate fluid pump (not shown). In such accumulators, the back pressure exerted by accumulator 36 can be changed using the separate fluid pump, instead of using a selected pressure to provide a selected force (for example, through the use of compressed gas and / or a spring). The charging pressure of the accumulator can be increased under circumstances, when it is necessary to discharge the drilling fluid into the annular space in order to increase the pressure. The charging pressure in the accumulator 36 can be relieved, for example, when the primary pumps 26 are restarted, or when the back pressure pump 42 is started.
    [00020] In the example of FIG. 1, the back pressure control system can be operated automatically by a controlled pressure drilling system ("MPD") 50. The MPD 50 system can include an operational control, such as a PC or touch screen 52, and a programmable logic controller (PLC) 54. PLC 54 can receive signals from various pressure sensors as input, including, but not limited to, pressure sensors 28 and 40 in FIG. 1. The PLC 52 can also operate the controllable and variable orifice regulators 38, 30, as well as the back pressure pump 42. As explained in the '981 van Riet patent referenced above, the MPD 50 system can operate the various components of the system , in order to maintain a selected fluid pressure in the discharge line 20 and thus within the annular space between the side wall of the well 11 and the drilling column 10 and, more specifically, at a selected pressure at the bottom of the well 11.
    [00021] The exemplary drilling system, including the MPD 50 system explained with reference to FIG. 1, is intended to explain the principles of MPD systems, and is not intended to limit the scope of such systems or the components actually used, in any particular example of marine drilling, as will be explained with reference to FIG. two.
    [00022] FIG. 2 shows another example of an MPD system, which can be used in marine drilling, in which a set of well flow control valves (safety valve set or "BOP") 102 can be arranged at the top of well 11, near the bottom of a body of water, or "mud line" 1. Drilling of well 11 and circulation of the drilling mud (34 in FIG. 1) can be performed by components similar to those shown and explained with reference to FIG . 1 above and to Figs. 3 to 5 below, but, in the present example, these components can be arranged on a platform (not shown) arranged on the water surface 2. Some of the previous components have been omitted from FIG. 2 for clarity of the illustration. An ascent conductor 100 can extend from BOP 102 to the platform (not shown for clarity of the illustration) on the water surface 2. A coating 109 can extend below the mud line 1 to a depth selected in well 11. BOP 102 can be attached to the top of the coating end. As shown, regulator 30, for example, a controllable orifice regulator, is coupled to the drill rise conductor 100, at a selected depth below the water surface 2. The remainder of the well drilling operations can be performed, substantially , as explained with reference to FIG. 1.
    [00023] An MPD 50 system, configured as explained with reference to FIG. 1, can be placed on the platform (not shown). The MPD system can receive an input signal from various pressure sensors and / or flow meters, for example, pressure sensor 28, fluidly connected to the rising conductor 100 and / or flow meters 139, 140, fluidly connected to a return line 138. An output signal from the MPD 50 system can control the opening of the controllable, adjustable orifice regulator 30. In the present example, fluid input to regulator 30 can be obtained from a line hydraulically connected to the riser 100, for example, a discharge duct, at a selected height above BOP 102. Although shown as being connected to the riser 100, in one or more distinct embodiments, the duct The discharge can be connected to the wellhead, or directly to the annular space, for example, below the rising conductor 100. The fluid outlet of regulator 30 can be coupled, through a check valve 130, to a return line of fluid 138. One valve bypass line 129 can be connected hydraulically to the upstream conductor 100, via a bypass line 131, and to a point downstream of regulator 30. In the present example, well 11 can be opened for the upstream conductor 102, and drilling can be performed without the use of a rotary spreader or rotary control head, as shown in FIG. 1.
    [00024] In the present example, fluid return line 138 can be maintained at a lower hydrostatic pressure (and its gradient) than would be exerted by a column of drilling fluid (mud 34 in FIG. 1) extended over a distance vertical traveled by the fluid return line 138. As shown, the fluid return line 138 extends from regulator 30 to the drilling platform (not shown), so that at least a vertical part of the return line fluid 138 is disposed below the water surface 2. The lower hydrostatic pressure (and its gradient) of the fluid return line 138 is maintained, by coupling the outlet of a gas compressor 132 to the return line 138, to a selected depth below the water surface 2. As shown, the gas compressor outlet 132 can be connected to the vertical part of the fluid return line 138 at the selected depth below the water surface 2. The gas compressor 1 32 can supply gas, air, nitrogen or other substantially inert gas ("gas") under pressure, through this coupling to the fluid return line 138.
    [00025] Coarse control can be obtained by operating the gas compressor 132 at a substantially constant rate or at a rate, which corresponds to the rate at which the drilling unit mud pump (s) (26 in FIG 1) operates (m). The fluid return line 138 can be coupled to a gas / liquid separator 136, disposed on the drilling platform (not shown). One of ordinary skill in the art will appreciate that any gas / liquid separator 136 can be used, according to embodiments described herein, such as, for example, a mechanical degasser or a centrifuge. A flow meter 139, coupled to a fluid discharge end of the gas / liquid separator 136, can measure the flow rate of liquid sludge leaving the separator 136, before returning the liquid sludge to tank 24. The flow rate of gas leaving the separator 136 can be measured by a flow meter 140 coupled to a gas discharge end of the gas / liquid separator 136, to help verify that the amount of gas entering the return line 138, is substantially the same as that coming out of the gas / liquid separator 136. This comparison can help, for example, to determine whether the gas is entering well 11, from an underground formation, or whether a leak is present in the system.
    [00026] In the present example, the lower hydrostatic pressure of the fluid column in the fluid return line 138 may cause regulator 30 to operate at a lower downstream pressure than would be the case if the fluid return line was filled only with a drilling mud column, for example, having a hydrostatic pressure only with the mud pumped into the well 11. In this way, the regulator 30 can be operated, so that a mud level 34a, in the conductor of ascent 100, can be maintained at a selected distance below the water surface 2, thereby exerting a lower hydrostatic pressure 11 than would be exerted by a column of drilling mud on the ascending conductor 100, extended to the surface of the water 2. In the present example, pressure signals from pressure sensor 28 and flow meters 140, 139 can be used by the MPD 50 system (or a stroke counter can be used in connection with probe pumps (26 in FIG 1 )) to operate regulator 30, to maintain a selected hydrostatic pressure in the rising conductor 100, above the measurement point, which corresponds to a fluid level 34A in the rising conductor 100. For example, PLC 54 (FIG. 1) can receive signals from the pressure sensor 28, flow meters 140, 139 and / or other sensors, and generate an output signal to operate controllable and variable orifice regulators 38, 30, as well as the counter-pressure pump 42, to maintain the fluid pressure in the well at a selected value. This operation of an MPD system can be substantially as described in U.S. Patent No. 6,904,981, granted to Van Riet, as described in more detail below. A person of ordinary skill in the art will realize that other sensors may be arranged at various locations within the system, for example, a pressure sensor may be arranged on a vertical part of the return line 138, a gas injection line, shown at 134, or elsewhere in the system, if necessary.
    [00027] Although the example explained above with reference to FIG. 2 can use an MPD 50 system to control regulator 30, to maintain a selected hydrostatic pressure, for example, on the rising conductor, in some instances, regulator 30 can be operated without an MPD 50 system. Regulator 30 can be operated manually or automatically, to maintain a selected hydrostatic pressure, when detected or measured by sensor 28. Therefore, the scope of the present disclosure is not limited to the use of an MPD 50 system. In some instances, regulator 30 may be a regulator of fixed orifice, and the hydrostatic pressure in the rising conductor 100 can be maintained by controlling a rate, at which the gas is pumped into the fluid return line 138.
    [00028] Another example of an MPD system, which can be used with the system and / or method described in this document, is shown in FIGS. 3 to 5. Although FIGS. 3 to 5 show an onshore drilling system using an MPD system, it will be realized that a marine drilling system can also use an MPD system. FIGS. 3 to 5 are also intended to explain and provide examples of MPD systems, and are not intended to limit the scope of those systems or components actually used, in any particular example of marine drilling, as explained above with reference to FIG. 2. FIG. 3 is a plan view, depicting a surface drilling system using an example MPD system. The drilling system 300 is shown, as being composed of a drilling rig 302, which is used to support drilling operations. Many of the components used on a 302 probe, such as a kelly (rigid rod), hydraulic wrench, wedges, drilling winch and other equipment, are not shown in order to facilitate representation. Probe 302 is used to support drilling and exploration operations in formation 304. As illustrated in FIG. 4, well 306 has already been partially drilled, liner 308 placed and cemented 309 in place. In the preferred embodiment, a liner seal mechanism, or wellhead distributor valve 310, is installed in liner 308 to optionally seal the annular space and act effectively as a valve to seal the open hole section when the drill is located above the valve.
    [00029] Drill column 312 supports a downhole assembly (BHA) 313, which includes a drill bit 320, a mud motor 318, a set of MWD / LWD sensors 319, which includes a 316 pressure transducer to determine the annular pressure, a check valve to prevent the counterflow of fluid from the annular space. The BHA also includes a telemetry package 322, which is used to transmit pressure, MWD / LWD, as well as drilling information to be received at the surface. Although FIG. 3 illustrate a BHA using a mud telemetry system, it will be realized that other telemetry systems, such as radiofrequency (RF), electromagnetic (EM) or transmission via drill column systems, can be used.
    [00030] As mentioned above, the drilling process requires the use of a drilling fluid 350, which is stored in reservoir 336. Reservoir 336 is in fluid communication with one or more mud pumps 338, which pump the drilling fluid 350 through conduit 340. Conduit 340 is connected to the last splice of drilling column 312, which passes through a rotating or spherical BOP 342. A rotating BOP 342, when activated, forces spherical elastomeric elements to rotate upward, closing the perforation column 312, isolating the pressure, but still allowing the rotation of the perforation column. Commercially available spherical BOPs, such as those manufactured by Varco International, are capable of insulating ring pressures greater than 10,000 psi (68947.6 kPa). The fluid 350 is pumped down through the drill column 312 and the BHA 313, and exits the drill bit 320, where it circulates the cuts away from the drill 320 and returns them over the open hole annular space 315 and then the annular space formed between the liner 308 and the drill column 312. The fluid 350 returns to the surface and passes through the disperser 317, through the conduit 324 and several telemetry systems and compensation tanks (not shown) .
    [00031] Next, fluid 350 proceeds to what is generally referred to as back pressure system 331. Fluid 350 enters back pressure system 331 and flows through a flow meter 326. Flow meter 326 can be a mass balance type or other high resolution flow meter. Using flow meter 326, an operator will be able to determine the amount of fluid 350, which was pumped into the well through drill column 312, and the amount of fluid 350 that returns from the well. Based on the differences in the amount of fluid 350 pumped compared to the fluid 350 returned, the operator is able to determine whether fluid 350 is being lost to formation 304, which may indicate that a fracture has occurred in the formation, that is, a significant negative fluid differential. Likewise, a significant positive differential would indicate the entry of formation fluid into the well.
    [00032] Fluid 350 proceeds to a wear resistant regulator 330. It will be realized that there are regulators designed to operate in an environment, where drilling fluid 350 contains substantially drilling cuts and other solids. Regulator 330 is of this type, and is also capable of operating at varying pressures and through multiple cycles. Fluid 350 exits regulator 330 and flows through valve 321. Fluid 350 is then processed by an optional degasser and a series of filters and a vibrating table 329 designed to remove contaminants, including cuts, from fluid 350. Fluid 350 then returns to reservoir 336. A flow circuit 319A is provided upstream of valve 325, to feed fluid 350 directly to a back pressure pump 328. Alternatively, back pressure pump 328 can be supplied with reservoir fluid, through conduit 319B, which is in fluid communication with reservoir 136 (maneuver tank). The maneuver tank is normally used in a probe to monitor fluid gains and losses during maneuver operations. A three-way valve 325 can be used to select circuit 319A, conduit 319B or isolate the back pressure system. Although the back pressure pump 328 is able to use the returned fluid to create a back pressure, by selecting the flow circuit 319A, it will be realized that the returned fluid may have contaminants that were not removed by the filter / vibrating table 329. wear on the 328 back pressure pump can be increased. Therefore, a back pressure can be created using the conduit 319A to supply reconditioned fluid to the back pressure pump 328.
    [00033] In operation, valve 325 can select conduit 319A or conduit 319B, and back pressure pump 328, engaged to ensure that sufficient flow passes through the regulator system, is able to maintain back pressure, even when there is no flow from annular space 315. Back pressure pump 328 may be able to provide up to about 2,200 psi (15,168.5 kPa) of back pressure; despite this, pumps with a higher pressure capacity can be selected.
    [00034] The pressure in the annular space, provided by the fluid, is a function of its density and the actual vertical depth, and is generally a linear function by approximation. As mentioned above, the additives added to the fluid in reservoir 336 are pumped to the bottom of the well to finally change the pressure gradient applied by fluid 350.
    [00035] A flow meter 352 can be positioned in the duct 300 to measure the amount of fluid to be pumped at the bottom of the well. It is observed that, by monitoring the flow meters 326, 352 and the volume pumped by the back pressure pump 328, the system is able to quickly determine the amount of fluid 350 that is being lost to the formation or, otherwise, the amount of formation fluid leaking into the borehole 306.
    [00036] An MPD system, as described with reference to Figs. 3 to 5, can also be used to monitor the pressure conditions of the well and predict pressure characteristics of the borehole 306 and annular space 315.
    [00037] FIG. 5 represents another example of the MPD system, in which a back pressure pump is not necessary to maintain sufficient flow through the regulator system, when the flow through the well needs to be stopped for any reason. In this example, an additional three-way valve 6 is placed downstream of probe pump 338 in conduit 340. This valve allows fluid from probe pumps to be completely diverted from conduit 340 to conduit 7, preventing flow from the probe pump 338 enter drill column 312. By maintaining the pumping action of pump 338, sufficient flow through the distribution valve to control back pressure can be ensured.
    [00038] To control a well event, a BOP can be closed, in the case of a large inflow fluid from the formation, such as a gas discharge, to effectively close the well, relieve pressure through the regulator and the cut-off manifold , and add the drilling fluid to provide additional annular pressure. An alternative method is sometimes called the "Borehole" method, which uses continuous circulation without closing the well. An extremely heavy fluid feed, for example, 18 pounds per gallon (ppg) (3.157 kg / 1) is constantly available during drilling operations below any installed liners. When a gas discharge or inflow fluid from the formation is detected, the extremely heavy fluid is added and circulated at the bottom of the well, causing the inflow fluid to come into solution with the circulating fluid. The inflow fluid starts to come out of the solution after reaching the casing shoe and is released through the regulator manifold. It is noted that, although the Sounder method provides continuous fluid circulation, it may also require additional circulation time, without drilling forward, to prevent additional influx of formation fluid and to allow the formation fluid to enter circulation with drilling fluid now with higher density.
    [00039] MPD pressure control systems and methods can also be used to control a large well event, such as a fluid inflow. When using MPD systems and methods, when an influx of fluid from the formation is detected, back pressure is increased, as opposed to the addition of extremely heavy fluid. Like the Sounder method, circulation is continued. With the increase in pressure, the influx of fluid from the formation passes into the solution in the circulating fluid and is released through the regulator manifold. Since the pressure has been increased, it is no longer necessary to circulate an extremely heavy fluid immediately. In addition, since back pressure is applied directly to the annular space, it quickly forces the forming fluid to enter the solution, instead of waiting until the extremely heavy fluid is circulated within the annular space.
    [00040] MPD systems and methods can also be used in non-continuous circulation systems. As mentioned above, continuous circulation systems are used to help stabilize formation, preventing sudden pressure drops, which occur when the mud pumps are turned off to join / break new pipe connections. This pressure drop is subsequently followed by a pressure spike when the pumps are switched on again for drilling operations. These variations in the annular pressure can adversely affect the plastering of mud from the borehole, and can result in the invasion of fluid into the formation. Back pressure can be applied in the annular space using an MDP system, after turning off the mud pumps, improving the sudden drop in pressure in the annular space, due to the pump shutdown condition, for a milder pressure drop. Before starting the pumps, the back pressure can be reduced, so that additional pump peaks are likewise reduced.
    [00041] The gas lift system, shown in FIG. 2, may require a relatively small amount of equipment to be deployed below the surface of the water 2 (for example, the connection to the return line 138 and the pressure sensor 28). This equipment is capable of operating in water depths of up to a few thousand feet for long periods of time. Since most equipment can be operated on the surface, for example, the compressor, a failure of this equipment can be significantly cheaper to replace, because the equipment is easily accessible. Additional compressors can also be added to the system without substantial effort.
    [00042] A system, according to embodiments disclosed herein, such as that shown in FIG. 2, does not require any sealing to isolate the fluid from the marine rising conductor from the fluid in the well. Specifically, because the gas injected into the return line can be easily removed from the riser fluid and / or the well fluid (for example, by release into the atmosphere), the separation of fluid from the riser and the well fluid is not required. In addition, the system, as shown in FIG. 2, can be used with a standard cut processing system, provided by standard marine drilling equipment.
    [00043] The system and method described in this document can allow the well pressure to be accurate and immediately controlled. The pressure and fluid volume in the return line can be reduced, while one or more probe pumps are turned off, since the return line can be evacuated, continuing to pump air or gas into the return line (138 in the FIG. 2). Thus, when one or more probe pumps are switched on again, the regulator (30 in the Figure) can be opened and the fluid from the riser can be quickly evacuated into the fluid return line, which can occur in just a few minutes. A gas lift system, as described in this document, may have a small fingerprint, thus allowing installation on any rig with a reasonable amount of deck space or possible deployment of another vessel. Finally, the system and method described in this document tend to have reduced fractions of formation gas (for example, hydrocarbon gases) in the returned drilling fluid. When pumping inert gas or air into the fluid return line, the gas fraction of the formation can be kept below the lower explosive limit (LEL) of methane, which is about 5%. Thus, the system and method described in this document can provide a higher level of security.
    [00044] The embodiments described herein should be interpreted as illustrative and not to restrict the rest of the disclosure, in any form whatsoever. Although the embodiments have been shown and described, many variations and modifications of the same can be made by a person skilled in the art, without departing from the scope and teachings disclosed here. Therefore, the scope of protection is not limited by the above description, but is only limited by the claims, including all equivalents of the subject of the claims. The disclosures of all Patents, Patent Applications and Publications cited in this document are hereby incorporated by reference, insofar as they provide procedural or other consistent and supplementary details to those set forth herein.
    权利要求:
    Claims (17)
    [0001]
    1. SYSTEM, characterized by the fact that it comprises: a drilling column extended inside a well hole, below a bottom of a body of water; a primary pump for selectively pumping a drilling fluid through the drilling column and into an annular space created between the drilling column and the well; a riser extending from an upper part of the well hole to a platform on the surface of the water body; a fluid discharge conduit in fluid communication with the ascending conductor; a controllable orifice regulator coupled to the discharge duct; a fluid return line extended from the regulator to the platform; a compressed gas source connected to the fluid return line at a selected depth below the surface of the water body; a separator coupled to the fluid return line; a flow meter coupled to a gas discharge end of the separator; a controller configured to receive an input signal from the flow meter and configured to compare a gas flow rate measured by the flow meter to a flow rate of gas pumped into the fluid return line.
    [0002]
    2. System, according to claim 1, characterized by the fact that it also comprises a pressure sensor disposed at a selected depth in the well hole or in the rising conductor.
    [0003]
    3. System according to claim 2, characterized in that the controller is configured to receive an input signal from the pressure sensor and configured to generate an output signal to operate the regulator, in which the regulator is operated to maintain a selected hydrostatic pressure in the rising conductor, at a selected distance below the surface of the water body.
    [0004]
    4. System according to claim 3, characterized by the fact that it still comprises at least one fluid flow meter to measure a fluid flow into the well hole or out of the well hole, and in which the controller receives an input signal from at least one fluid flow meter, the controller generating an output signal to operate the regulator, to maintain the fluid pressure in the well bore at a selected value.
    [0005]
    5. System, according to claim 1, characterized by the fact that the controllable orifice regulator is arranged at a selected depth below the surface of the water body.
    [0006]
    6. System, according to claim 1, characterized by the fact that it also comprises a pressure sensor connected to the fluid return line.
    [0007]
    7. System, according to claim 1, characterized by the fact that the fluid return line, extended from the regulator to the platform, includes a vertical part located below the surface of the water body.
    [0008]
    8. System, according to claim 1, characterized by the fact that it also comprises a check valve coupled to the fluid return line, between the controllable orifice regulator and an inlet in the fluid return line, coupled to the source of compressed gas.
    [0009]
    9. System, according to claim 1, characterized by the fact that the pressure sensor is coupled to the discharge duct near the fluid regulator.
    [0010]
    10. METHOD, characterized by the fact that it comprises: pumping drilling fluid through a drilling column extended into a well hole, extended below a bottom of a body of water, leaving the bottom of the drilling column, and inwards the annular space of the well; discharge fluid from the annular space of the well and into a rising conductor arranged above the top of the well hole, the rising conductor extended to the surface of the water body, discharge fluid from the rising conductor through a return line fluid, the fluid return line extending from below the surface of the water body to the surface of the water body; pump gas under pressure into the return line at a selected depth below the surface of the water body; maintain a selected hydrostatic pressure in the rising conductor at a chosen distance below the surface of the water body; separating the gas from a fluid returned by the return line near the surface of the water body; measure a flow rate of the gas separated from the fluid returned by the return line; and comparing the flow rate of the gas separated from the fluid returned by the return line with a flow rate of the gas pumped into the return line.
    [0011]
    11. Method according to claim 10, characterized by the fact that it still comprises the measurement of a fluid pressure in the rising conductor, at a selected depth, and operation of the controllable fluid regulator arranged between the rising conductor and the line fluid return, based on measurement, to maintain the selected hydrostatic pressure in the rising conductor, at the selected distance, below the surface of the water body.
    [0012]
    12. Method, according to claim 10, characterized by the fact that it also comprises the adjustment of the hydrostatic pressure in the rising conductor, through the adjustment of a flow rate of gas pumped into the return line.
    [0013]
    13. METHOD, characterized by the fact that it comprises: pumping drilling fluid through a drilling column extended into a well hole, extended below the bottom of a body of water, exiting through the bottom of the drilling column, and into the annular space of the well hole; discharge fluid from the annular space of the well hole into a rising conductor arranged over the top of the well hole and into a discharge duct, the discharge duct including a fluid regulator and a return line of fluid coupled to a fluid regulator outlet and extended to the water surface; pump gas under pressure into the return line, at a selected depth below the water surface; control a rate at which gas is pumped into the return line and operate a back pressure pump to apply back pressure to the discharge duct, to maintain a fluid level in the rising conductor, at a selected distance below the surface of the mass of water; wherein a controller receives input signals from at least one of a pressure sensor in the discharge line, a first flow meter coupled to a liquid discharge end of a separator configured to separate the gas from the fluid in the return line, and a second flow meter coupled to a gas discharge end of the separator, and where the controller sends output signals to operate the fluid regulator and back pressure pump to maintain the fluid level in the rising conductor at a distance selected below the surface of the water body.
    [0014]
    14. Method, according to claim 13, characterized by the fact that it still comprises the operation of the fluid regulator in response to a flow rate measured in the discharge duct near the fluid regulator.
    [0015]
    15. Method, according to claim 13, characterized by the fact that it still comprises the restriction of fluid flow from the return line to the fluid regulator.
    [0016]
    16. Method, according to claim 13, characterized by the fact that it still comprises the escape of gas from the return line to the atmosphere.
    [0017]
    17. Method, according to claim 13, characterized by the fact that the rate control, in which the gas is pumped into the return line, comprises the comparison of the rate, in which the gas is pumped into the return line , with a rate, at which drilling fluid is pumped through the drill string.
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    同族专利:
    公开号 | 公开日
    NO341948B1|2018-02-26|
    MX354169B|2018-02-16|
    RU2586129C1|2016-06-10|
    MX2014013023A|2015-02-04|
    GB201419418D0|2014-12-17|
    BR112014026864A2|2017-06-27|
    GB2520182B|2017-01-11|
    CN104428485A|2015-03-18|
    US9376875B2|2016-06-28|
    GB2520182A|2015-05-13|
    US20150083429A1|2015-03-26|
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    WO2013163642A1|2013-10-31|
    CA2871620C|2017-01-03|
    AU2013251321B2|2016-04-28|
    NO20141409A1|2014-11-24|
    AU2013251321A1|2014-11-13|
    CN104428485B|2018-06-08|
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    法律状态:
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2020-02-04| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-08-18| B09A| Decision: intention to grant|
    2020-12-08| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 29/04/2013, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
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    US201261639815P| true| 2012-04-27|2012-04-27|
    US61/639,815|2012-04-27|
    PCT/US2013/038615|WO2013163642A1|2012-04-27|2013-04-29|Wellbore annular pressure control system and method using gas lift in drilling fluid return line|
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