AU2008365249A1 - Pressure and flow control in drilling operations - Google Patents

Description

WO 2010/071656 PCT/US2008/087686 5 PRESSURE AND FLOW CONTROL IN DRILLING OPERATIONS TECHNICAL FIELD 10 The present disclosure relates generally to equipment utilized and operations performed in conjunction with well drilling operations and, in an embodiment described herein, more particularly provides for pressure and flow control in drilling operations. 15 BACKGROUND Managed pressure drilling is well known as the art of precisely controlling bottom hole pressure during drilling by utilizing a closed annulus and a means for regulating 20 pressure in the annulus. The annulus is typically closed during drilling through use of a rotating control device (RCD, also known as a rotating control head or rotating blowout preventer) which seals about the drill pipe as it rotates. 25 The means for regulating pressure in the annulus can include a choke interconnected in the mud return line and, in some applications, a backpressure pump to apply pressure to the annulus while connections are made in the drill pipe string. Unfortunately, use of a backpressure pump requires WO 2010/071656 PCT/US2008/087686 -2 substantial capital investment, the additional pump takes up scarce space on offshore rigs, the pump output is difficult to control accurately and use of the pump interferes with normal operations on a drilling rig. 5 Therefore, it may be seen that improvements are needed in the art of controlling pressure and flow in drilling operations. These improvements may include the elimination of a separate backpressure pump in drilling operations, but the improvements could be utilized in conjunction with a 10 backpressure pump, if desired. SUMMARY In carrying out the principles of the present disclosure, systems and methods are provided which solve at 15 least one problem in the art. One example is described below in which flow through a standpipe line and flow through a bypass line are independently variable, thereby enabling more accurate control over flow and pressure during the drilling operation. Another example is described below 20 in which, after a drill pipe connection is made, the standpipe line and drill pipe are filled and pressurized prior to closing off flow through the bypass line. In one aspect, a well drilling system is provided by the disclosure below for use with a pump which pumps 25 drilling fluid through a drill string while drilling a wellbore. The system includes a flow control device which regulates flow from the pump to an interior of the drill string, and another flow control device which regulates flow from the pump through a line in communication with an 30 annulus formed between the drill string and the wellbore. Flow is simultaneously permitted through the flow control devices.

WO 2010/071656 PCT/US2008/087686 -3 In another aspect, a method of maintaining a desired bottom hole pressure during a well drilling operation is provided. The method includes the step of: dividing flow of drilling fluid between a line in communication with an 5 interior of a drill string and a line in communication with an annulus formed between the drill string and a wellbore. The flow dividing step includes permitting flow through a flow control device interconnected between a pump and the interior of the drill string. The flow dividing step 10 further includes permitting flow through another flow control device interconnected between the pump and the annulus, while flow is permitted through the first flow control device. In yet another aspect, a method of making a connection 15 in a drill string, while maintaining a desired bottom hole pressure, includes the steps of: pumping a drilling fluid from a rig mud pump and through a mud return choke during the entire connection making method; 20 determining a desired annulus pressure which corresponds to the desired bottom hole pressure during the entire connection making method, the annulus being formed between the drill string and a wellbore; regulating flow of the drilling fluid through the mud 25 return choke, thereby maintaining the desired annulus pressure, during the entire connection making method; increasing flow through a bypass flow control device and decreasing flow through a standpipe flow control device, thereby diverting at least a portion of the drilling fluid 30 flow from a line in communication with an interior of the drill string to a line in communication with the annulus; WO 2010/071656 PCT/US2008/087686 -4 preventing flow through the standpipe flow control device; then making the connection in the drill string; and then decreasing flow through the bypass flow control 5 device and increasing flow through the standpipe flow control device, thereby diverting at least a portion of the drilling fluid flow to the line in communication with the interior of the drill string from the line in communication with the annulus. 10 These and other features, advantages, benefits and objects will become apparent to one of ordinary skill in the art upon careful consideration of the detailed description of representative embodiments of the disclosure hereinbelow and the accompanying drawings, in which similar elements are 15 indicated in the various figures using the same reference numbers. BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a schematic view of a well drilling system 20 and method embodying principles of the present disclosure; FIG. 2 is a schematic view of another configuration of the well drilling system; FIG. 3 is a schematic view of a pressure and flow control system which may be used in the well drilling system 25 and method; and FIG. 4 is a flowchart of a method for making a drill string connection which may be used in the well drilling system and method.

WO 2010/071656 PCT/US2008/087686 -5 DETAILED DESCRIPTION It is to be understood that the various embodiments of the present disclosure described herein may be utilized in 5 various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of the present disclosure. The embodiments are described merely as examples of useful applications of the principles of the 10 disclosure, which is not limited to any specific details of these embodiments. In the following description of the representative embodiments of the disclosure, directional terms, such as "above", "below", "upper", "lower", etc., are used for 15 convenience in referring to the accompanying drawings. In general, "above", "upper", "upward" and similar terms refer to a direction toward the earth's surface along a wellbore, and "below", "lower", "downward" and similar terms refer to a direction away from the earth's surface along the 20 wellbore. Representatively and schematically illustrated in FIG. 1 is a well drilling system 10 and associated method which embody principles of the present disclosure. In the system 10, a wellbore 12 is drilled by rotating a drill bit 14 on 25 an end of a drill string 16. Drilling fluid 18, commonly known as mud, is circulated downward through the drill string 16, out the drill bit 14 and upward through an annulus 20 formed between the drill string and the wellbore 12, in order to cool the drill bit, lubricate the drill 30 string, remove cuttings and provide a measure of bottom hole pressure control. A non-return valve 21 (typically a flapper-type check valve) prevents flow of the drilling WO 2010/071656 PCT/US2008/087686 -6 fluid 18 upward through the drill string 16 (e.g., when connections are being made in the drill string). Control of bottom hole pressure is very important in managed pressure drilling, and in other types of drilling 5 operations. Preferably, the bottom hole pressure is accurately controlled to prevent excessive loss of fluid into the earth formation surrounding the wellbore 12, undesired fracturing of the formation, undesired influx of formation fluids into the wellbore, etc. In typical managed 10 pressure drilling, it is desired to maintain the bottom hole pressure just greater than a pore pressure of the formation, without exceeding a fracture pressure of the formation. In typical underbalanced drilling, it is desired to maintain the bottom hole pressure somewhat less than the pore 15 pressure, thereby obtaining a controlled influx of fluid from the formation. Nitrogen or another gas, or another lighter weight fluid, may be added to the drilling fluid 18 for pressure control. This technique is useful, for example, in 20 underbalanced drilling operations. In the system 10, additional control over the bottom hole pressure is obtained by closing off the annulus 20 (e.g., isolating it from communication with the atmosphere and enabling the annulus to be pressurized at or near the 25 surface) using a rotating control device 22 (RCD). The RCD 22 seals about the drill string 16 above a wellhead 24. Although not shown in FIG. 1, the drill string 16 would extend upwardly through the RCD 22 for connection to, for example, a rotary table (not shown), a standpipe line 26, 30 kelley (not shown), a top drive and/or other conventional drilling equipment.

WO 2010/071656 PCT/US2008/087686 -7 The drilling fluid 18 exits the wellhead 24 via a wing valve 28 in communication with the annulus 20 below the RCD 22. The fluid 18 then flows through mud return lines 30, 73 to a choke manifold 32, which includes redundant chokes 34 5 (only one of which may be used at a time). Backpressure is applied to the annulus 20 by variably restricting flow of the fluid 18 through the operative choke(s) 34. The greater the restriction to flow through the choke 34, the greater the backpressure applied to the annulus 20. 10 Thus, bottom hole pressure can be conveniently regulated by varying the backpressure applied to the annulus 20. A hydraulics model can be used, as described more fully below, to determine a pressure applied to the annulus 20 at or near the surface which will result in a desired bottom hole 15 pressure, so that an operator (or an automated control system) can readily determine how to regulate the pressure applied to the annulus at or near the surface (which can be conveniently measured) in order to obtain the desired bottom hole pressure. 20 Pressure applied to the annulus 20 can be measured at or near the surface via a variety of pressure sensors 36, 38, 40, each of which is in communication with the annulus. Pressure sensor 36 senses pressure below the RCD 22, but above a blowout preventer (BOP) stack 42. Pressure sensor 25 38 senses pressure in the wellhead below the BOP stack 42. Pressure sensor 40 senses pressure in the mud return lines 30, 73 upstream of the choke manifold 32. Another pressure sensor 44 senses pressure in the standpipe line 26. Yet another pressure sensor 46 senses 30 pressure downstream of the choke manifold 32, but upstream of a separator 48, shaker 50 and mud pit 52. Additional WO 2010/071656 PCT/US2008/087686 -8 sensors include temperature sensors 54, 56, Coriolis flowmeter 58, and flowmeters 62, 64, 66. Not all of these sensors are necessary. For example, the system 10 could include only two of the three flowmeters 5 62, 64, 66. However, input from the sensors is useful to the hydraulics model in determining what the pressure applied to the annulus 20 should be during the drilling operation. In addition, the drill string 16 may include its own 10 sensors 60, for example, to directly measure bottom hole pressure. Such sensors 60 may be of the type known to those skilled in the art as pressure while drilling (PWD), measurement while drilling (MWD) and/or logging while drilling (LWD). These drill string sensor systems generally 15 provide at least pressure measurement, and may also provide temperature measurement, detection of drill string characteristics (such as vibration, weight on bit, stick slip, etc.), formation characteristics (such as resistivity, density, etc.) and/or other measurements. Various forms of 20 telemetry (acoustic, pressure pulse, electromagnetic, etc.) may be used to transmit the downhole sensor measurements to the surface. Additional sensors could be included in the system 10, if desired. For example, another flowmeter 67 could be used 25 to measure the rate of flow of the fluid 18 exiting the wellhead 24, another Coriolis flowmeter (not shown) could be interconnected directly upstream or downstream of a rig mud pump 68, etc. Fewer sensors could be included in the system 10, if 30 desired. For example, the output of the rig mud pump 68 could be determined by counting pump strokes, instead of by using flowmeter 62 or any other flowmeters.

WO 2010/071656 PCT/US2008/087686 -9 Note that the separator 48 could be a 3 or 4 phase separator, or a mud gas separator (sometimes referred to as a "poor boy degasser"). However, the separator 48 is not necessarily used in the system 10. 5 The drilling fluid 18 is pumped through the standpipe line 26 and into the interior of the drill string 16 by the rig mud pump 68. The pump 68 receives the fluid 18 from the mud pit 52 and flows it via a standpipe manifold 70 to the standpipe 26, the fluid then circulates downward through the 10 drill string 16, upward through the annulus 20, through the mud return lines 30, 73, through the choke manifold 32, and then via the separator 48 and shaker 50 to the mud pit 52 for conditioning and recirculation. Note that, in the system 10 as so far described above, 15 the choke 34 cannot be used to control backpressure applied to the annulus 20 for control of the bottom hole pressure, unless the fluid 18 is flowing through the choke. In conventional overbalanced drilling operations, such a situation will arise whenever a connection is made in the 20 drill string 16 (e.g., to add another length of drill pipe to the drill string as the wellbore 12 is drilled deeper), and the lack of circulation will require that bottom hole pressure be regulated solely by the density of the fluid 18. In the system 10, however, flow of the fluid 18 through 25 the choke 34 can be maintained, even though the fluid does not circulate through the drill string 16 and annulus 20, while a connection is being made in the drill string. Thus, pressure can still be applied to the annulus 20 by restricting flow of the fluid 18 through the choke 34, even 30 though a separate backpressure pump may not be used. Instead, the fluid 18 is flowed from the pump 68 to the choke manifold 32 via a bypass line 72, 75 when a connection WO 2010/071656 PCT/US2008/087686 - 10 is made in the drill string 16. Thus, the fluid 18 can bypass the standpipe line 26, drill string 16 and annulus 20, and can flow directly from the pump 68 to the mud return line 30, which remains in communication with the annulus 20. 5 Restriction of this flow by the choke 34 will thereby cause pressure to be applied to the annulus 20. As depicted in FIG. 1, both of the bypass line 75 and the mud return line 30 are in communication with the annulus 20 via a single line 73. However, the bypass line 75 and 10 the mud return line 30 could instead be separately connected to the wellhead 24, for example, using an additional wing valve (e.g., below the RCD 22), in which case each of the lines 30, 75 would be directly in communication with the annulus 20. Although this might require some additional 15 plumbing at the rig site, the effect on the annulus pressure would be essentially the same as connecting the bypass line 75 and the mud return line 30 to the common line 73. Thus, it should be appreciated that various different configurations of the components of the system 10 may be 20 used, without departing from the principles of this disclosure. Flow of the fluid 18 through the bypass line 72, 75 is regulated by a choke or other type of flow control device 74. Line 72 is upstream of the bypass flow control device 25 74, and line 75 is downstream of the bypass flow control device. Flow of the fluid 18 through the standpipe line 26 is substantially controlled by a valve or other type of flow control device 76. Note that the flow control devices 74, 30 76 are independently controllable, which provides substantial benefits to the system 10, as described more fully below.

WO 2010/071656 PCT/US2008/087686 - 11 Since the rate of flow of the fluid 18 through each of the standpipe and bypass lines 26, 72 is useful in determining how bottom hole pressure is affected by these flows, the flowmeters 64, 66 are depicted in FIG. 1 as being 5 interconnected in these lines. However, the rate of flow through the standpipe line 26 could be determined even if only the flowmeters 62, 64 were used, and the rate of flow through the bypass line 72 could be determined even if only the flowmeters 62, 66 were used. Thus, it should be 10 understood that it is not necessary for the system 10 to include all of the sensors depicted in FIG. 1 and described herein, and the system could instead include additional sensors, different combinations and/or types of sensors, etc. 15 In another beneficial feature of the system 10, a bypass flow control device 78 and flow restrictor 80 may be used for filling the standpipe line 26 and drill string 16 after a connection is made, and equalizing pressure between the standpipe line and mud return lines 30, 73 prior to 20 opening the flow control device 76. Otherwise, sudden opening of the flow control device 76 prior to the standpipe line 26 and drill string 16 being filled and pressurized with the fluid 18 could cause an undesirable pressure transient in the annulus 20 (e.g., due to flow to the choke 25 manifold 32 temporarily being lost while the standpipe line and drill string fill with fluid, etc.). By opening the standpipe bypass flow control device 78 after a connection is made, the fluid 18 is permitted to fill the standpipe line 26 and drill string 16 while a 30 substantial majority of the fluid continues to flow through the bypass line 72, thereby enabling continued controlled application of pressure to the annulus 20. After the pressure in the standpipe line 26 has equalized with the WO 2010/071656 PCT/US2008/087686 - 12 pressure in the mud return lines 30, 73 and bypass line 75, the flow control device 76 can be opened, and then the flow control device 74 can be closed to slowly divert a greater proportion of the fluid 18 from the bypass line 72 to the 5 standpipe line 26. Before a connection is made in the drill string 16, a similar process can be performed, except in reverse, to gradually divert flow of the fluid 18 from the standpipe line 26 to the bypass line 72 in preparation for adding more 10 drill pipe to the drill string 16. That is, the flow control device 74 can be gradually opened to slowly divert a greater proportion of the fluid 18 from the standpipe line 26 to the bypass line 72, and then the flow control device 76 can be closed. 15 Note that the flow control device 78 and flow restrictor 80 could be integrated into a single element (e.g., a flow control device having a flow restriction therein), and the flow control devices 76, 78 could be integrated into a single flow control device 81 (e.g., a 20 single choke which can gradually open to slowly fill and pressurize the standpipe line 26 and drill string 16 after a drill pipe connection is made, and then open fully to allow maximum flow while drilling). However, since typical conventional drilling rigs are 25 equipped with the flow control device 76 in the form of a valve in the standpipe manifold 70, and use of the standpipe valve is incorporated into usual drilling practices, the individually operable flow control devices 76, 78 are presently preferred. The flow control devices 76, 78 are at 30 times referred to collectively below as though they are the single flow control device 81, but it should be understood WO 2010/071656 PCT/US2008/087686 - 13 that the flow control device 81 can include the individual flow control devices 76, 78. Another alternative is representatively illustrated in FIG. 2. In this configuration of the system 10, the flow 5 control device 78 is in the form of a choke, and the flow restrictor 80 is not used. The flow control device 78 depicted in FIG. 2 enables more precise control over the flow of the fluid 18 into the standpipe line 26 and drill string 16 after a drill pipe connection is made. 10 Note that each of the flow control devices 74, 76, 78 and chokes 34 are preferably remotely and automatically controllable to maintain a desired bottom hole pressure by maintaining a desired annulus pressure at or near the surface. However, any one or more of these flow control 15 devices 74, 76, 78 and chokes 34 could be manually controlled without departing from the principles of this disclosure. A pressure and flow control system 90 which may be used in conjunction with the system 10 and associated methods of 20 FIGS. 1 & 2 is representatively illustrated in FIG. 3. The control system 90 is preferably fully automated, although some human intervention may be used, for example, to safeguard against improper operation, initiate certain routines, update parameters, etc. 25 The control system 90 includes a hydraulics model 92, a data acquisition and control interface 94 and a controller 96 (such as a programmable logic controller or PLC, a suitably programmed computer, etc.). Although these elements 92, 94, 96 are depicted separately in FIG. 3, any 30 or all of them could be combined into a single element, or the functions of the elements could be separated into WO 2010/071656 PCT/US2008/087686 - 14 additional elements, other additional elements and/or functions could be provided, etc. The hydraulics model 92 is used in the control system 90 to determine the desired annulus pressure at or near the 5 surface to achieve the desired bottom hole pressure. Data such as well geometry, fluid properties and offset well information (such as geothermal gradient and pore pressure gradient, etc.) are utilized by the hydraulics model 92 in making this determination, as well as real-time sensor data 10 acquired by the data acquisition and control interface 94. Thus, there is a continual two-way transfer of data and information between the hydraulics model 92 and the data acquisition and control interface 94. For the purposes of this disclosure, it is important to appreciate that the data 15 acquisition and control interface 94 operates to maintain a substantially continuous flow of real-time data from the sensors 44, 54, 66, 62, 64, 60, 58, 46, 36, 38, 40, 56, 67 to the hydraulics model 92, so that the hydraulics model has the information it needs to adapt to changing circumstances 20 and to update the desired annulus pressure, and the hydraulics model operates to supply the data acquisition and control interface substantially continuously with a value for the desired annulus pressure. A suitable hydraulics model for use as the hydraulics 25 model 92 in the control system 90 is REAL TIME HYDRAULICS (TM) provided by Halliburton Energy Services, Inc. of Houston, Texas USA. Another suitable hydraulics model is provided under the trade name IRIS (TM), and yet another is available from SINTEF of Trondheim, Norway. Any suitable 30 hydraulics model may be used in the control system 90 in keeping with the principles of this disclosure.

WO 2010/071656 PCT/US2008/087686 - 15 A suitable data acquisition and control interface for use as the data acquisition and control interface 94 in the control system 90 are SENTRY (TM) and INSITE (TM) provided by Halliburton Energy Services, Inc. Any suitable data 5 acquisition and control interface may be used in the control system 90 in keeping with the principles of this disclosure. The controller 96 operates to maintain a desired setpoint annulus pressure by controlling operation of the mud return choke 34. When an updated desired annulus 10 pressure is transmitted from the data acquisition and control interface 94 to the controller 96, the controller uses the desired annulus pressure as a setpoint and controls operation of the choke 34 in a manner (e.g., increasing or decreasing flow through the choke as needed) to maintain the 15 setpoint pressure in the annulus 20. This is accomplished by comparing the setpoint pressure to a measured annulus pressure (such as the pressure sensed by any of the sensors 36, 38, 40), and increasing flow through the choke 34 if the measured pressure is greater 20 than the setpoint pressure, and decreasing flow through the choke if the measured pressure is less than the setpoint pressure. Of course, if the setpoint and measured pressures are the same, then no adjustment of the choke 34 is required. This process is preferably automated, so that no 25 human intervention is required, although human intervention may be used if desired. The controller 96 may also be used to control operation of the standpipe flow control devices 76, 78 and the bypass flow control device 74. The controller 96 can, thus, be 30 used to automate the processes of diverting flow of the fluid 18 from the standpipe line 26 to the bypass line 72 prior to making a connection in the drill string 16, then WO 2010/071656 PCT/US2008/087686 - 16 diverting flow from the bypass line to the standpipe line after the connection is made, and then resuming normal circulation of the fluid 18 for drilling. Again, no human intervention may be required in these automated processes, 5 other than to initiate each process in turn. Referring additionally now to FIG. 4, a schematic flowchart is provided for a method 100 for making a drill pipe connection in the well drilling system 10 using the control system 90. Of course, the method 100 may be used in 10 other well drilling systems, and with other control systems, in keeping with the principles of this disclosure. The drill pipe connection process begins at step 102, in which the process is initiated. A drill pipe connection is typically made when the wellbore 12 has been drilled far 15 enough that the drill string 16 must be elongated in order to drill further. In step 104, the flow rate output of the pump 68 may be decreased. By decreasing the flow rate of the fluid 18 output from the pump 68, it is more convenient to maintain 20 the choke 34 within its most effective operating range (typically, from about 30% to about 70% of maximum opening) during the connection process. However, this step is not necessary if, for example, the choke 34 would otherwise remain within its effective operating range. 25 In step 106, the setpoint pressure changes due to the reduced flow of the fluid 18 (e.g., to compensate for decreased fluid friction in the annulus 20 between the bit 14 and the wing valve 28 resulting in reduced equivalent circulating density). The data acquisition and control 30 interface 94 receives indications (e.g., from the sensors 58, 60, 62, 66, 67) that the flow rate of the fluid 18 has decreased, and the hydraulics model 92 in response WO 2010/071656 PCT/US2008/087686 - 17 determines that a changed annulus pressure is desired to maintain the desired bottom hole pressure, and the controller 96 uses the changed desired annulus pressure as a setpoint to control operation of the choke 34. 5 In a slightly overbalanced managed pressure drilling operation, the setpoint pressure would likely increase, due to the reduced equivalent circulating density, in which case flow through the choke 34 would be decreased in response. However, in some operations (such as, underbalanced drilling 10 operations in which gas or another light weight fluid is added to the drilling fluid 18 to decrease bottom hole pressure), the setpoint pressure could decrease (e.g., due to production of liquid downhole). In step 108, the restriction to flow of the fluid 18 15 through the choke 34 is changed, due to the changed desired annulus pressure in step 106. As discussed above, the controller 96 controls operation of the choke 34, in this case changing the restriction to flow through the choke to obtain the changed setpoint pressure. Also as discussed 20 above, the setpoint pressure could increase or decrease. Steps 104, 106 and 108 are depicted in the FIG. 4 flowchart as being performed concurrently, since the setpoint pressure and mud return choke restriction can continuously vary, whether in response to each other, in 25 response to the change in the mud pump output and in response to other conditions, as discussed above. In step 109, the bypass flow control device 74 gradually opens. This diverts a gradually increasing proportion of the fluid 18 to flow through the bypass line 30 72, instead of through the standpipe line 26. In step 110, the setpoint pressure changes due to the reduced flow of the fluid 18 through the drill string 16 WO 2010/071656 PCT/US2008/087686 - 18 (e.g., to compensate for decreased fluid friction in the annulus 20 between the bit 14 and the wing valve 28 resulting in reduced equivalent circulating density). Flow through the drill string 16 eventually ceases when the 5 bypass flow control device 74 is opened, since the bypass line 72 becomes the path of least resistance to flow. The data acquisition and control interface 94 receives indications (e.g., from the sensors 58, 60, 62, 66, 67) that the flow rate of the fluid 18 through the drill pipe 16 and 10 annulus 20 has decreased, and the hydraulics model 92 in response determines that a changed annulus pressure is desired to maintain the desired bottom hole pressure, and the controller 96 uses the changed desired annulus pressure as a setpoint to control operation of the choke 34. 15 In a slightly overbalanced managed pressure drilling operation, the setpoint pressure would likely increase, due to the reduced equivalent circulating density, in which case flow through the choke 34 would be decreased in response. However, in some operations (such as, underbalanced drilling 20 operations in which gas or another light weight fluid is added to the drilling fluid 18 to decrease bottom hole pressure), the setpoint pressure could decrease (e.g., due to production of liquid downhole). In step 111, the restriction to flow of the fluid 18 25 through the choke 34 is changed, due to the changed desired annulus pressure in step 110. As discussed above, the controller 96 controls operation of the choke 34, in this case changing the restriction to flow through the choke to obtain the changed setpoint pressure. Also as discussed 30 above, the setpoint pressure could increase or decrease. Steps 109, 110 and 111 are depicted in the FIG. 4 flowchart as being performed concurrently, since the WO 2010/071656 PCT/US2008/087686 - 19 setpoint pressure and mud return choke restriction can continuously vary, whether in response to each other, in response to the bypass flow control device 74 opening and in response to other conditions, as discussed above. 5 In step 112, the pressures in the standpipe line 26 and the annulus 20 at or near the surface (indicated by sensors 36, 38, 40, 44) equalize. At this point, the bypass flow control device 74 should be fully open, and substantially all of the fluid 18 is flowing through the bypass line 72, 10 75 and not through the standpipe line 26 (since the bypass line represents the path of least resistance). Static pressure in the standpipe line 26 should substantially equalize with pressure in the lines 30, 73, 75 upstream of the choke manifold 32. 15 In step 114, the standpipe flow control device 81 is closed. The separate standpipe bypass flow control device 78 should already be closed, in which case only the valve 76 would be closed in step 114. In step 116, a standpipe bleed valve (not shown) would 20 be opened to bleed pressure and fluid from the standpipe line 26 in preparation for breaking the connection between the kelley or top drive and the drill string 16. At this point, the standpipe line 26 is vented to atmosphere. In step 118, the kelley or top drive is broken off of 25 the drill string 16, another stand of drill pipe is connected to the drill string, and the kelley or top drive is made up to the top of the drill string. This step is performed in accordance with conventional drilling practice. In step 120, the standpipe bleed valve is closed. The 30 standpipe line 26 is, thus, isolated again from atmosphere, but the standpipe line and the newly added stand of drill WO 2010/071656 PCT/US2008/087686 - 20 pipe is substantially empty (i.e., not filled with the fluid 18) and un-pressurized. In step 122, the standpipe bypass flow control device 78 opens (in the case of the valve and flow restrictor 5 configuration of FIG. 1) or gradually opens (in the case of the choke configuration of FIG. 2). In this manner, the fluid 18 is allowed to fill the standpipe line 26 and the newly added stand of drill pipe, as indicated in step 124. Eventually, the pressure in the standpipe line 26 will 10 equalize with the pressure in the annulus 20 at or near the surface, as indicated in step 126. However, substantially all of the fluid 18 will still flow through the bypass line 72 at this point. Static pressure in the standpipe line 26 should substantially equalize with pressure in the lines 30, 15 73, 75 upstream of the choke manifold 32. In step 128, the standpipe flow control device 76 is opened in preparation for diverting flow of the fluid 18 to the standpipe line 26 and thence through the drill string 16. The standpipe bypass flow control device 78 is then 20 closed. Note that, by previously filling the standpipe line 26 and drill string 16, and equalizing pressures between the standpipe line and the annulus 20, the step of opening the standpipe flow control device 76 does not cause any significant undesirable pressure transients in the annulus 25 or mud return lines 30, 73. Substantially all of the fluid 18 still flows through the bypass line 72, instead of through the standpipe line 26, even though the standpipe flow control device 76 is opened. Considering the separate standpipe flow control devices 30 76, 78 as a single standpipe flow control device 81, then the flow control device is gradually opened to slowly fill the standpipe line 26 and drill string 16, and then fully WO 2010/071656 PCT/US2008/087686 - 21 opened when pressures in the standpipe line and annulus 20 are substantially equalized. In step 130, the bypass flow control device 74 is gradually closed, thereby diverting an increasingly greater 5 proportion of the fluid 18 to flow through the standpipe line 26 and drill string 16, instead of through the bypass line 72. During this step, circulation of the fluid 18 begins through the drill string 16 and wellbore 12. In step 132, the setpoint pressure changes due to the 10 flow of the fluid 18 through the drill string 16 and annulus 20 (e.g., to compensate for increased fluid friction resulting in increased equivalent circulating density). The data acquisition and control interface 94 receives indications (e.g., from the sensors 60, 64, 66, 67) that the 15 flow rate of the fluid 18 through the wellbore 12 has increased, and the hydraulics model 92 in response determines that a changed annulus pressure is desired to maintain the desired bottom hole pressure, and the controller 96 uses the changed desired annulus pressure as a 20 setpoint to control operation of the choke 34. The desired annulus pressure may either increase or decrease, as discussed above for steps 106 and 108. In step 134, the restriction to flow of the fluid 18 through the choke 34 is changed, due to the changed desired 25 annulus pressure in step 132. As discussed above, the controller 96 controls operation of the choke 34, in this case changing the restriction to flow through the choke to obtain the changed setpoint pressure. Steps 130, 132 and 134 are depicted in the FIG. 4 30 flowchart as being performed concurrently, since the setpoint pressure and mud return choke restriction can continuously vary, whether in response to each other, in WO 2010/071656 PCT/US2008/087686 - 22 response to the bypass flow control device 74 closing and in response to other conditions, as discussed above. In step 135, the flow rate output from the pump 68 may be increased in preparation for resuming drilling of the 5 wellbore 12. This increased flow rate maintains the choke 34 in its optimum operating range, but this step (as with step 104 discussed above) may not be used if the choke is otherwise maintained in its optimum operating range. In step 136, the setpoint pressure changes due to the 10 increased flow of the fluid 18 (e.g., to compensate for increased fluid friction in the annulus 20 between the bit 14 and the wing valve 28 resulting in increased equivalent circulating density). The data acquisition and control interface 94 receives indications (e.g., from the sensors 15 58, 60, 62, 66, 67) that the flow rate of the fluid 18 has increased, and the hydraulics model 92 in response determines that a changed annulus pressure is desired to maintain the desired bottom hole pressure, and the controller 96 uses the changed desired annulus pressure as a 20 setpoint to control operation of the choke 34. In a slightly overbalanced managed pressure drilling operation, the setpoint pressure would likely decrease, due to the increased equivalent circulating density, in which case flow through the choke 34 would be increased in 25 response. In step 137, the restriction to flow of the fluid 18 through the choke 34 is changed, due to the changed desired annulus pressure in step 136. As discussed above, the controller 96 controls operation of the choke 34, in this 30 case changing the restriction to flow through the choke to obtain the changed setpoint pressure. Also as discussed above, the setpoint pressure could increase or decrease.

WO 2010/071656 PCT/US2008/087686 - 23 Steps 135, 136 and 137 are depicted in the FIG. 4 flowchart as being performed concurrently, since the setpoint pressure and mud return choke restriction can continuously vary, whether in response to each other, in 5 response to the change in the mud pump output and in response to other conditions, as discussed above. In step 138, drilling of the wellbore 12 resumes. When another connection is needed in the drill string 16, the steps 102-138 can be repeated. 10 Steps 140 and 142 are included in the FIG. 4 flowchart for the connection method 100 to emphasize that the control system 90 continues to operate throughout the method. That is, the data acquisition and control interface 94 continues to receive data from the sensors 36, 38, 40, 44, 46, 54, 56, 15 58, 62, 64, 66, 67 and supplies appropriate data to the hydraulics model 92. The hydraulics model 92 continues to determine the desired annulus pressure corresponding to the desired bottom hole pressure. The controller 96 continues to use the desired annulus pressure as a setpoint pressure 20 for controlling operation of the choke 34. It will be appreciated that all or most of the steps described above may be conveniently automated using the control system 90. For example, the controller 96 may be used to control operation of any or all of the flow control 25 devices 34, 74, 76, 78, 81 automatically in response to input from the data acquisition and control interface 94. Human intervention would preferably be used to indicate to the control system 90 when it is desired to begin the connection process (step 102), and then to indicate when a 30 drill pipe connection has been made (step 118), but substantially all of the other steps could be automated (i.e., by suitably programming the software elements of the WO 2010/071656 PCT/US2008/087686 - 24 control system 90). However, it is envisioned that all of the steps 102-142 can be automated, for example, if a suitable top drive drilling rig (or any other drilling rig which enables drill pipe connections to be made without 5 human intervention) is used. It may now be fully appreciated that the above disclosure provides substantial improvements to the art of pressure and flow control in drilling operations. Among these improvements is elimination of the necessity for use 10 of a separate backpressure pump to maintain annulus pressure during drill pipe connections. Also among these improvements is the coordinated gradual diversion of drilling fluid 18 between the standpipe line 26 and bypass line 72 in a manner which eliminates, or at least 15 substantially eliminates, undesirable pressure transients in the annulus 20 when connections are made. The above disclosure provides a well drilling system 10 for use with a pump 68 which pumps drilling fluid 18 through a drill string 16 while drilling a wellbore 12. A flow 20 control device 81 regulates flow from the pump 68 to an interior of the drill string 16. Another flow control device 74 regulates flow from the pump 68 to a line 75 in communication with an annulus 20 formed between the drill string 16 and the wellbore 12. Flow is simultaneously 25 permitted through the flow control devices 74, 81. The flow control device 81 may be operable independently from operation of the flow control device 74. The pump 68 may be a rig mud pump in communication via the flow control device 81 with a standpipe line 26 for 30 supplying the drilling fluid 18 to the interior of the drill string 16. The system 10 is preferably free of any other pump which applies pressure to the annulus 20.

WO 2010/071656 PCT/US2008/087686 - 25 The system 10 can also include another flow control device 34 which variably restricts flow from the annulus 20. An automated control system 90 may control operation of the flow control devices 34, 74 to maintain a desired annulus 5 pressure while a connection is made in the drill string 16. The control system 90 may also control operation of the flow control device 81 to maintain the desired annulus pressure while the connection is made in the drill string 16. The above disclosure also describes a method of 10 maintaining a desired bottom hole pressure during a well drilling operation. The method includes the steps of: dividing flow of drilling fluid 18 between a line 26 in communication with an interior of a drill string 16 and a line 75 in communication with an annulus 20 formed between 15 the drill string 16 and a wellbore 12; the flow dividing step including permitting flow through a standpipe flow control device 81 interconnected between a pump 68 and the interior of the drill string 16; and the flow dividing step including permitting flow through a bypass flow control 20 device 74 interconnected between the pump 68 and the annulus 20, while flow is permitted through the standpipe flow control device 81. The method may also include the step of closing the standpipe flow control device 81 after pressures in the line 25 26 in communication with the interior of the drill string 16 and the line 75 in communication with the annulus 20 equalize. The method may include the steps of: making a connection in the drill string 16 after the step of closing 30 the standpipe flow control device 81; then permitting flow through the standpipe flow control device 81 while permitting flow through the bypass flow control device 74; WO 2010/071656 PCT/US2008/087686 - 26 and then closing the bypass flow control device 74 after pressures again equalize in the line 26 in communication with the interior of the drill string 16 and in the line 75 in communication with the annulus 20. 5 The method may also include the step of permitting flow through another flow control device (e.g., choke 34) continuously during the flow dividing, standpipe flow control device closing, connection making and bypass flow control device closing steps, thereby maintaining a desired 10 annulus pressure corresponding to the desired bottom hole pressure. The method may also include the step of determining the desired annulus pressure in response to input of sensor measurements to a hydraulics model 92 during the drilling 15 operation. The step of maintaining the desired annulus pressure may include automatically varying flow through the flow control device (e.g., choke 34) in response to comparing a measured annulus pressure with the desired annulus pressure. 20 The above disclosure also describes a method 100 of making a connection in a drill string 16 while maintaining a desired bottom hole pressure. The method 100 includes the steps of: pumping a drilling fluid 18 from a rig mud pump 68 and 25 through a mud return choke 34 during the entire connection making method 100; determining a desired annulus pressure which corresponds to the desired bottom hole pressure during the entire connection making method 100, the annulus 20 being 30 formed between the drill string 16 and a wellbore 12; WO 2010/071656 PCT/US2008/087686 - 27 regulating flow of the drilling fluid 18 through the mud return choke 34, thereby maintaining the desired annulus pressure, during the entire connection making method 100; increasing flow through a bypass flow control device 74 5 and decreasing flow through a standpipe flow control device 81, thereby diverting at least a portion of the drilling fluid flow from a line 26 in communication with an interior of the drill string 16 to a line 75 in communication with the annulus 20; 10 preventing flow through the standpipe flow control device 81; then making the connection in the drill string 16; and then decreasing flow through the bypass flow control device 74 and increasing flow through the standpipe flow 15 control device 81, thereby diverting at least another portion of the drilling fluid flow to the line 26 in communication with the interior of the drill string 16 from the line 75 in communication with the annulus 20. The steps of increasing flow through the bypass flow 20 control device 74 and decreasing flow through the standpipe flow control device 81 may also include simultaneously permitting flow through the bypass and standpipe flow control devices 74, 81. The steps of decreasing flow through the bypass flow 25 control device 74 and increasing flow through the standpipe flow control device 81 further comprise simultaneously permitting flow through the bypass and standpipe flow control devices 74, 81. The method 100 may also include the step of equalizing 30 pressure between the line 26 in communication with the interior of the drill string 16 and the line 75 in WO 2010/071656 PCT/US2008/087686 - 28 communication with the annulus 20. This pressure equalizing step is preferably performed after the step of increasing flow through the bypass flow control device 74, and prior to the step of decreasing flow through the standpipe flow 5 control device 81. The method 100 may also include the step of equalizing pressure between the line 26 in communication with the interior of the drill string 16 and the line 75 in communication with the annulus 20. This pressure equalizing 10 step is preferably performed after the step of decreasing flow through the bypass flow control device 74, and prior to the step of increasing flow through the standpipe flow control device 81. The step of determining the desired annulus pressure 15 may include determining the desired annulus pressure in response to input of sensor measurements to a hydraulics model 92. The step of maintaining the desired annulus pressure may include automatically varying flow through the mud return choke 34 in response to comparing a measured 20 annulus pressure with the desired annulus pressure. Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, 25 substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of the present disclosure. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example 30 only, the spirit and scope of the present invention being limited solely by the appended claims and their equivalents.

Claims (19)

1. A well drilling system for use with a pump which pumps drilling fluid through a drill string while drilling a 5 wellbore, the system comprising: a first flow control device which regulates flow from the pump to an interior of the drill string; a second flow control device which regulates flow from the pump through a line in communication with an annulus 10 formed between the drill string and the wellbore; and wherein flow is simultaneously permitted through the first and second flow control devices.

2. The system of claim 1, wherein the first flow control device is operable independently from operation of 15 the second flow control device.

3. The system of claim 1, wherein the pump is a rig mud pump in communication via the first flow control device with a standpipe line for supplying the drilling fluid to the interior of the drill string. 20

4. The system of claim 1, wherein the pump is a rig mud pump, and wherein the system is free of any other pump which applies pressure to the annulus.

5. The system of claim 1, further comprising a third flow control device which variably restricts flow from the 25 annulus, and wherein an automated control system controls operation of the second and third flow control devices to maintain a desired annulus pressure while a connection is made in the drill string.

6. The system of claim 5, wherein the control system 30 further controls operation of the first flow control device WO 2010/071656 PCT/US2008/087686 - 30 to maintain the desired annulus pressure while the connection is made in the drill string.

7. A method of maintaining a desired bottom hole pressure during a well drilling operation, the method 5 comprising the steps of: dividing flow of drilling fluid between a line in communication with an interior of a drill string and a line in communication with an annulus formed between the drill string and a wellbore; 10 the flow dividing step including permitting flow through a first flow control device interconnected between a pump and the interior of the drill string; and the flow dividing step including permitting flow through a second flow control device interconnected between 15 the pump and the annulus, while flow is permitted through the first flow control device.

8. The method of claim 7, further comprising the step of closing the first flow control device after pressures in the line in communication with the interior of the drill 20 string and the line in communication with the annulus equalize.

9. The method of claim 8, further comprising the steps of: making a connection in the drill string after the first 25 flow control device closing step; then permitting flow through the first flow control device while permitting flow through the second flow control device; and then closing the second flow control device after 30 pressures again equalize in the line in communication with WO 2010/071656 PCT/US2008/087686 - 31 the interior of the drill string and in the line in communication with the annulus.

10. The method of claim 9, further comprising the step of permitting flow through a third flow control device 5 continuously during the flow dividing, first flow control device closing, connection making and second flow control device closing steps, thereby maintaining a desired annulus pressure corresponding to the desired bottom hole pressure.

11. The method of claim 10, further comprising the 10 step of determining the desired annulus pressure in response to input of sensor measurements to a hydraulics model during the drilling operation.

12. The method of claim 11, wherein the step of maintaining the desired annulus pressure further comprises 15 automatically varying flow through the third flow control device in response to comparing a measured annulus pressure with the desired annulus pressure.

13. A method of making a connection in a drill string while maintaining a desired bottom hole pressure, the method 20 comprising the steps of: pumping a drilling fluid from a rig mud pump and through a mud return choke during the entire connection making method; determining a desired annulus pressure which 25 corresponds to the desired bottom hole pressure during the entire connection making method; regulating flow of the drilling fluid through the mud return choke, thereby maintaining the desired annulus pressure, during the entire connection making method; 30 increasing flow through a bypass flow control device and decreasing flow through a standpipe flow control device, WO 2010/071656 PCT/US2008/087686 - 32 thereby diverting at least a first portion of the drilling fluid flow from a line in communication with an interior of the drill string to a line in communication with an annulus; preventing flow through the standpipe flow control 5 device; then making the connection in the drill string; and then decreasing flow through the bypass flow control device and increasing flow through the standpipe flow control device, thereby diverting at least a second portion 10 of the drilling fluid flow to the line in communication with the interior of the drill string from the line in communication with the annulus.

14. The method of claim 13, wherein the steps of increasing flow through the bypass flow control device and 15 decreasing flow through the standpipe flow control device further comprise simultaneously permitting flow through the bypass and standpipe flow control devices.

15. The method of claim 13, wherein the steps of decreasing flow through the bypass flow control device and 20 increasing flow through the standpipe flow control device further comprise simultaneously permitting flow through the bypass and standpipe flow control devices.

16. The method of claim 13, further comprising the step of equalizing pressure between the line in 25 communication with the interior of the drill string and the line in communication with the annulus, the pressure equalizing step being performed after the step of increasing flow through the bypass flow control device, and the pressure equalizing step being performed prior to the step 30 of decreasing flow through the standpipe flow control device. WO 2010/071656 PCT/US2008/087686 - 33

17. The method of claim 13, further comprising the step of equalizing pressure between the line in communication with the interior of the drill string and the line in communication with the annulus, the pressure 5 equalizing step being performed after the step of decreasing flow through the bypass flow control device, and the pressure equalizing step being performed prior to the step of increasing flow through the standpipe flow control device. 10

18. The method of claim 13, wherein the step of determining the desired annulus pressure further comprises determining the desired annulus pressure in response to input of sensor measurements to a hydraulics model.

19. The method of claim 18, wherein the step of 15 maintaining the desired annulus pressure further comprises automatically varying flow through the mud return choke in response to comparing a measured annulus pressure with the desired annulus pressure.