Pressure and flow control in drilling operations.

(54) Title: CONTROL OF PRESSURE AND FLOW IN DRILLING OPERATIONS.

(54) Title: PRESSURE AND FLOW CONTROL IN DRILLING OPERATIONS.

(57) Summary

A well drilling system includes a flow control device that regulates the flow from a sounding pump to a drill pipe, the flow control device will be interconnected between the pump and a vertical pipe distributor, and another device for flow control that regulates flow through a pipeline in communication with a circular crown. Simultaneous flow through flow control devices is allowed. One method of maintaining a desired downhole pressure includes dividing the flow of drilling fluids between a pipeline in communication with an internal drill pipeline and a pipeline in communication with a circular crown; The step to divide the flow includes allowing a flow through a flow control device interconnected between a pump and a vertical pipe distributor.

(57) Abstract

A well drilling system ineludes a flow control device regulating flow from a rig pump to a drill string, the flow control device being interconnected between the pump and a standpipe manifold, and another flow control device regulating flow through a line in communication with an annulus. Flow is simultaneously permitted through the flow control devices. A method of maintaining a desired bottom hole pressure ineludes dividing drilling fluid flow between a line in communication with a drill string interior and a line in communication with an annulus; the flow dividing step including permitting flow through a flow control device interconnected between a pump and a standpipe manifold.

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PATENT TITLE NO. 340331 _SE_

Yes CftFl'AMA OI: t ΟΝΟΜΙΛ

Mexican Institute of Industrial Property

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Owner (s): HALLIBURTON ENERGY SERVICES, INC.

Address: 10200 Bellaire Boulevard, Houston, Texas, 77072, USA

Name: PRESSURE AND FLOW CONTROL IN DRILLING OPERATIONS. Classification: lnt.CI.8: E21B21 / 08; E21B34 / 06

Inventor (s): CHRISTOPHER J. BERNARD

REQUEST

Number: International filing date:

MX / a / 2013/013045 May 09, 2011

PRIORITY

Country: Date: Number:

Validity: Twenty years

Expiration Date: May 9, 2031 • The reference patent is granted based on articles 1, 2, section V, 6, section III, and 59 of the Industrial Property Law.

In accordance with article 23 of the Industrial Property Law, this patent has a validity of twenty non-extendable aftas, stupid from the date of filing of the international application and will be subject to the payment of the fee to maintain the rights in force. ..... 'i ··, ·, ·.

Whoever signs this title does so based on the provisions of articles 6 * fraly Hly 7 ° bis 2 of the Industrial Property Law (Diario Oficie de la Federación (DOF) 06/27/1991, amended on 02/08 / 1994, 10/25/1996. 12/26/1997, 05/17/1999, 01/26/2004, 06/16/2005, 01/25/2006, 06/05/2009, 06/01/2010, 06/18/2010, 2B / 06/2010, 01/27/2012 and 04/09/2012), articles i, 3rd fraction V subsection a), sub subsection ni) 4th and 12th fractions I and lll of the Regulations of the Mexican Property Institute Industrial (DOF 12/14/1999, amended on 07/01/2002, 07/07/2004, 07/28/2004 and 09/07/2007); Articles 1, 3, 4, 5, section V, subsection a), sub subsection ii), 16 frictions I and lll and 30 of the Organic Statute of the Mexican Institute of the. Industrial Property (D UF 12/27/1998, amended on 10/10/2020 ^ 2, 07/29/2004, 08/04/2004 and 09/13/20 &lt;7); 1st, 3% and 5th subsection a) and foreword MfN &amp; páHafo &lt;M Acuesto φΜ details powers in the Deputy Directors General, Coordinated ^ Divisional Directors, Head of the Regional Offices. Divisional Deputy Directors, β Departmental Coordinators and other subordinates of the Mexican Institute of ΐόΜΤοίΜΜΜΝΪΜΜ. (DOF 12/15/1999, amended on 02/04/2000, 07/29/2004, 08/04/2004 ^ 09/13/2007) 3

Issue Date: July 5, 2016

DIVISIONAL DEPUTY DIRECTOR OF EXAMINATION OF PATENT FUND, MECHANICAL, ELECTRICAL AND REGIATPQA AREAS FOR INDUSTRIAL AND

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Aranai No. 550, Floor 1 Col. Pueblo Santa Mana Tepepar Xocbimíí.cc. C P. 16020.

Mexico City

TeL (55) 53 34 07 00 ww.impi aob.mx

PED

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MX / 2016/52597

PRESSURE AND FLOW CONTROL IN OPERATIONS

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FIELD OF THE INVENTION

The present disclosure generally relates to equipment used and the operations performed in conjunction with well drilling operations and, in an embodiment described herein, more particularly provides pressure and flow control in drilling operations.

BACKGROUND OF THE INVENTION

Controlled pressure drilling is well known as the technique to accurately control downhole pressure during drilling by using a closed circular crown and a means to regulate the pressure in the circular crown. The circular crown is typically closed during drilling through the use of a rotary control device (RCD, also known as a rotary control plug or rotary control valve) that closes around the drill pipe as it rotates.

SUMMARY OF THE INVENTION

Therefore, it will be appreciated that improvements in the technique for controlling pressure and flow in drilling operations could be beneficial.

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MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL

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BRIEF DESCRIPTION OF THE DRAWINGS

Figure 1 is a schematic view of a well drilling system and a method incorporating the principles of the present disclosure.

Figure 2 is a schematic view of another configuration of the system for drilling wells.

Figure 3 is a schematic block diagram of a pressure and flow control system that can be used in the well drilling system and method.

Figure 4 is a flow chart of a method for making a connection for a drill pipe that can be used in the system and methods for drilling wells.

Figure 5 is a schematic block diagram of another configuration of the pressure and flow control system.

Figures 6, 7, and 8 are schematic block diagrams of various configurations of a predictive device that can be used in the pressure and flow control system of Figure 5.

Figure 9 is a schematic view of another configuration of the system for drilling wells.

MEXICAN INSTITUTE .í

OF PROPERTY V »i» ™ 2Sf _ _, _. _Λ industrial

Figure 10 is a schematic view of another

IMPI system configuration for well drilling.

DETAILED DESCRIPTION OF THE INVENTION

In figure 1, a system for drilling wells 10 and ur is schematically and representatively illustrated:

associated method that can incorporate the principles of the present description. In system 10, a bore is drilled by rotating a bit 14 over one end of drill pipe 16. Drilling fluid 18, commonly known as mud, is circulated downward through drill pipe 16, out of bit 14, and upward through a circular crown 20 formed between drill pipe and bore 12 , to cool the bit, lubricate the drill pipe, eliminate cutouts and provide a measure of downhole pressure control. A non-return shutoff valve 21 (typically a chanelled check valve) prevents the flow of drilling fluid 18 upward through drill pipe 16 (for example, when connections are being made to the drill pipe) .

Downhole pressure control is very important in controlled pressure drilling and other types of drilling operations. Preferably, the

IMPI

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DI LA PROntPAD downhole pressure is controlled by mafié'ú^si? '^{TO THE}pr ^ m: ou ^ to avoid excessive fluid loss é! l ia^,^,,Kiffft^,Sci^,n¹ land surrounding the borehole 12, unwanted formation fracturing, unwanted ingress of formation fluids into the borehole, etc.

In typical controlled pressure drilling, it is desired to maintain the downhole pressure just slightly greater than a formation pore pressure, without exceeding a formation fracture pressure. This technique is especially useful in situations where the margin between pore pressure and fracture is relatively small.

In typical underbalanced drilling, it is desired to keep the downhole pressure somewhat less than the pore pressure, thereby obtaining a controlled inflow of fluid from the formation. In typical overbalanced drilling, you want to keep the downhole pressure slightly higher than the pore pressure, thereby preventing (or at least mitigating) the ingress of fluid from the formation.

Nitrogen or other gas, or another lighter weight fluid, can be added to the drilling fluid 18 for pressure control. This technique is useful, for example, in underbalanced drilling operations.

In system 10, additional control is obtained!

IMPT _

MEXICAN INSTITUTE 7Λ

OE THE PROPERTY

INDUSTRIAL tarpaulin l over the downhole pressure when closing the circular crown 20 (for example, isolating it from communication with the atmosphere and allowing the circular crown to be pressurized at or near the surface) using a rotary control device 22 (RCD). RCD 22 seals around drill pipe 16 above a wellhead 24. Although not shown in Figure 1, drill pipe 16 could be extended upward through RCD 22 for connection to, for example, a turntable (not shown), a standpipe 26, Kelley (not shown), a top drive and / or other conventional drill rig.

Drilling fluid 18 exits to head i.

well 24 via a wing valve 28 in communication with the circular crown 20 below the RCD 22. Fluid 18 then flows through the pipes to return sludge 30, 73 to a manifold regulator 32, including redundant regulators 34 ( only one of them could be used at a time). Back pressure is applied to the circular crown 20 by a variably restrictive flow; of fluid 18 through operational regulators 34.

The greater the flow restriction through regulator 34, the greater the back pressure applied to the

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IMPI

IHSTITVK MEXICAN PROPERTY circular crown 20. Thus, the pressure in eT^TRThe well (for example, the pressure at the bottom of the borehole Γ77 Ta pressure in a footing of the casing at the bottom of the well, the pressure in a particular formation or zone, etc.) can be conveniently regulated by varying the back pressure applied to the circular crown 20. A hydraulic model, as will be described in more detail below, can be used to determine a pressure applied to the circular crown 20 at or near the surface which will result in a desired pressure at the bottom of the well, so that an operator (or an automated control system;

can easily determine how to regulate the pressure applied to the circular crown at or near the surface (which can be conveniently measured) to obtain the desired downhole pressure.

The pressure applied to the circular crown 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 circular crown. Pressure sensor 36 detects the pressure below RCD 22, but above a control valve chain (BOP) 42. Pressure sensor 38 detects the pressure at the wellhead below the BOP chain 42 . The 4U pressure sensor detects the pressure in the pipes for sludge return 30, _Ί IMPI

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OF THE PROPERTY

INDUSTRIAL upstream of regulator manifold 32.

Another pressure sensor 44 detects the pressure in the vertical pipeline 26. Still, another pressure sensor 46 detects the pressure downstream of the regulator manifold 32, although upstream of a separator 48, a stirrer 50 and a mud pit 52. Sensors Additional include temperature sensors 54, 56, a Coriolis flow meter 58, and flow meters 62, 64, 66.

Not all of these sensors are necessary. For example, system 10 could include only two of the three flow meters 62, 64, 66. However, input from all available sensors is useful for the hydraulic model in determining what pressure is applied to the crown. circular 20 that should be during the drilling operation.

Other types of sensors can be used, if desired. For example, the flowmeter does not need to be a Coriolis flowmeter, as a turbine flowmeter, acoustic flowmeter, or other type of flowmeter could be used instead.

In addition, drill pipe 16 may itself include sensors 60, for example, to directly measure downhole pressure. These sensors 60 may be of the type known to those of skill in the art

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INSTITUTO M'ZiCAITO (% / · .., &lt;'sÁ technique as pressure during drilling (while drilling (MWD) and / or diagram ..... churantc bar drilling (LWD). These sensor systems in drill pipes generally provide at least one pressure measurement, and can also provide a temperature measurement, detecting the characteristics of the drill pipe (such as vibration, weight on the bit, jerkiness). , etc.), formation characteristics (such as, resistivity, density, etc.) and / or other measurements. Various forms of wired or wireless telemetry (acoustic, pressure pulse, electromagnetic, etc.) can be used to transmit the sensor measurements at the bottom of the well to the surface.

If desired, 10 additional sensors could also be included in the system. For example, another flow meter 67 could be used to measure the flow rate of fluid '18 exiting wellhead 24, another Coriolis flow meter (not shown) could be interconnected directly upstream or downstream of a pump probing machine 68 etc.

If desired, fewer sensors could be included in system 10. For example, the output of sounding pump 68 could be determined by counting the pumps, rather than using flow meter 62 or any other Mexican institute

OF THE PROPERTY

INDUSTRIAL flow meters.

Note that the separator 48 could be a 3 or 4 phase separator, or a sludge-gas separator (sometimes referred to as a sludge separator degasser). However, in system 10 separator 48 is not necessarily used.

<td>The</td><td>drilling fluid 18 is pumped</td><td>through</td><td>of</td>

<td>The pipe</td><td>vertical 26 and inside the</td><td>pipeline</td><td>of</td>

<td>drilling</td><td>16 by means of the probe pump 68.</td><td>The bomb</td><td> 62</td>

it receives the fluid 18 from the mud pit 52 and it flows via a vertical pipe distributor 70 to the vertical pipe 26. The fluid then circulates down through the drill pipe 16, up through the crown circulate 20, through the mud return pipes 30, 73, through the multiple regulator 32, and then via the separator 48 and the agitator 50 towards the mud pit 52 for conditioning and reciroulation.

Note that, in system 10 as described above, regulator 34 cannot be used to control back pressure applied to circular crown 20 for control of downhole pressure, unless fluid 18 is flow through the regulator. In conventional overbalanced drilling operations, a lack of fluid flow 18 will occur, for example,

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whenever a connection is made in the Tü'Slí ^ í to bore 16 (for example, to add another drill pipe length to the drill pipe as bore 12 is drilled deeper), and the missing circulation will require that the pressure at the bottom of the well be regulated only by the density of the fluid 18.

In system 10, however, the flow of fluid through regulator 34 can be maintained, even though fluid does not circulate through drill pipe 16 and ring gear 20, while a connection is being made to the perforating pipe. In this way, pressure can still be applied to the circular crown by restricting the flow of fluid 18 through regulator 34, even though a separate back pressure pump may not be used.

When the fluid 18 is not circulating through the drill pipe 16 and the circular crown 20 (for example, when a connection is made in the drill pipe), the fluid is flowed from the pump 68 to the regulator manifold 32 via a diversion pipe 72, 75. In this way, the fluid 18 can divert the vertical pipe 26, the perforation pipe 16 and the circular crown 20, and can flow directly from the pump 6 "to the pipe to return mud 30, which remains in

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communication with the circular crown 20. The

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apply pressure to the circular crown 20 (for example, in typical controlled pressure drilling).

As shown in figure 1, both the diversion pipe 75 and the mud return pipe 30 are in communication with the circular crown 20 via a single pipe 73. However, the diversion pipe 75 and the mud return pipe 30 could be separated rather than connected to the wellhead 24, for example, using an additional wing valve (for example, below RCD 22), in in which case each of the pipes 30 could be in direct communication with the circular crown 20.

Although this might require some additional piping at the borehole site, the effect on the pressure of the circular crown could be essentially the same as that of the connection of the bypass pipe 75 and the pipe for return of mud 30 to the common pipe 73. In this way, it should be appreciated that various different configurations of the components of the system 10 can be used, without departing from the principles of this description.

Fluid flow 18 through bypass line 72, 75 is regulated by a regulator and other

<td>device</td><td>for</td><td>12 control of</td><td>f lu jo</td><td>IMPI Mexican institute C OF THE PROPERTY »r» »,. -C. Λ · '# INDUSTRIAL 74. Pipe 72 is</td>

<td>upstream</td><td>of the</td><td>device</td><td>for</td><td>flow control do</td>

<td>deviation 74,</td><td>and</td><td>The pipe</td><td> 75</td><td>is downstream of</td>

deviation flow control device.

Fluid flow 18 through riser 26 is substantially controlled by a valve or other type of flow control device 76. Note that flow control devices 74, 76 can be controlled independently, providing substantial benefits. to system 10, as will be described in greater detail below.

Because the flow rate of fluid 18 through each of the vertical and diversion pipes

26, 72 is useful in determining how much downhole pressure is affected by these flows. In Figure 1, flow meters 64, 66 interconnected in these pipes are shown. However, the flow rate through riser 26 could be determined even if only flow meters 62, 64 were used, and the flow rate through bypass tubing 72 could be determined, even if only flow meters 62, 66 are used. Thus, it should be understood that it is not necessary for the system 10 to include all the sensors represented in Figure 1 and described herein, and 13

IMPI

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MEXICAN INSTITUTE OF LA MONEDAD _η . ,. ,,, INDUSTRIAL - instead the system could include additional sensors, different combinations and / or types of sensors, etc.

In another beneficial feature of system 10, a bypass flow control device 78 and a flow reducer 80 can be used to fill the vertical pipe 26 and the drill pipe 16 after a connection is made in the drill pipe. , and to equalize the pressure between the vertical pipe and the mud return pipes 30, 73 before opening the flow control device 76. Otherwise, a sudden opening of the flow control device 76 before the vertical pipe 26 and the perforation pipe 16 are filled and pressurized with the fluid 18 could cause an undesirable transient pressure in the circular crown 20 (for example , due to the flow to the regulator manifold 32 which will be temporarily lost while the vertical pipe and the drill pipe are filled with the fluid, etc.).

By opening the vertical pipe diversion flow control device 78 after a connection is made, the fluid 18 is allowed to fill the vertical pipe 26 and the drill pipe 16, while a substantial majority of the fluid continues to flow through bypass pipe 72, thereby allowing

IMPI

IEXEXAN INSTITUTE OF PROPERTY

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a continuous controlled application of pressure c circular 20. After Ί3 'ΡΓδΰΊόΤΙ —T ~ r vertical pipe 26 has been equalized with the pressure in the mud return pipes 30, 73 and the diversion pipe 75, gj.

flow control device 76 can be opened, and then flow control device 74 can be closed to slowly divert a larger proportion of fluid 18 from bypass line 72 to vertical line 26.

Before a connection is made to drill pipe 16, a similar process can be performed, except that in reverse, to gradually divert fluid flow 18 from riser 26 to diversion pipe 72 in preparation for add more drill pipe to drill pipe 16. That is, the flow control device 74 can be gradually opened to slowly divert a greater proportion of the fluid 18 from the vertical pipe 26 to the diversion pipe 72, and then the flow control device 76 can be closed.

Note that the flow control device and the flow reducer 80 could be integrated in a single element (for example, a flow control device that has a flow restriction therein), and the flow control devices 76 78 could be

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OF PROPERTY C&gt; a

INDUSTRIAL integrated into a single flow control device 81 (for example, a single regulator that can gradually open to slowly fill and pressurize riser 26 and drill pipe 16 after a drill pipe connection is made and , lusqc, fully open to allow maximum flow during drilling).

However, because typical conventional drill rigs are equipped with a flow control device 76 in the form of a valve in the vertical pipe manifold 70, and the use of the vertical pipe valve is incorporated in the As usual drilling practices, flow control devices 76, 78 that can be operated individually are currently preferred. The flow control devices: r 76, 78 are, at the times referred to collectively below as if they were the individual flow control device 81, although it should be understood that the flow control device 81 may include the individual flow control devices 76, 78.

Another alternative is representatively illustrated in Figure 2. In this configuration of system 10, e. flow control device 78 is in the form of a

JL x'i Jl J. flcíjí? · '' INSTITUTO MiXICMta regulator, and the reducer device for flow control is not used 78 r epre sen ί-gt'du ^,· Πτ- “ίΝ&gt; - figure 2, allows more precise control over the flow of the fluid 18 in the vertical pipe 26 and the perforation pipe 16 after a connection of the perforation pipe is made.

Note that each of the flow control devices 74, 76, 78, and preferably regulators 34 can be remotely and automatically controlled to maintain a desired downhole pressure by maintaining a desired pressure in the ring gear at or near Of the surface. However, any one or more of these flow control devices 74, 76, 78 and regulators 34 could be controlled manually without departing from the principles of this disclosure.

In FIG. 3, a pressure and flow control system 90 is illustratively illustrated that can be used in conjunction with system 10 and the associated methods of FIGS. 1 and 2. Control system 90 is preferably fully automated, although You can use some human intervention, for example, to protect against improper operation, start certain routines, update parameters, etc.

Control system 90 includes a model

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OF THE PROPERTY

INDUSTRIAL hydraulic 92, an interface for obtaining and controlling data 94, and a controller 96 (such as a programmable logic controller or PLC, a properly programmed computer, etc.). Although these elements 92, 94, 96 are represented separately in Figure 3, any or all of them could be combined into a single element, or the functions of the elements could be separated into additional elements, other elements could be provided and / or additional functions, etc.

Hydraulic model 92 is used in control system 90 to determine the desired pressure in the circular crown at or near the surface to achieve the desired pressure at the bottom of the well. Data such as well geometry, fluid properties, and information from i.

Compensation well (such as the geothermal gradient and the pore pressure gradient, etc.) are used by the hydraulic model 92 to make this determination, as well as the data from the sensor in real time obtained by the interface to obtain and control data 94.

In this way there is a continuous bidirectional transfer of data and information between the model. ' Hydraulic 92 and the data collection and control interface 94. It is important to appreciate that the data collection and control interface 94 operates to maintain flow.

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MEXlCAN INSTITUTE: 1 ₇ Substantially continuous data in time reaí'Ncpirovei ^^ S from sensors 44, 54, 66, 62, 64, 60, 50 ', 40,^1,1 30, ·· 3 · θτ

56, 67 towards the hydraulic model 92, so that e!

The hydraulic model has the information necessary to adapt to changing circumstances and update the desired pressure in the circular crown and the hydraulic model works to supply the interface for obtaining and controlling data substantially continuously with a value for the desired pressure in the circular crown.

A suitable hydraulic model for use with ccmc hydraulic model 92 in control system 90 is the

REAL TIME HYDRAULICS (TM) provided by Halliburton

Energy Services, Inc. From Houston, Texas, USA. Another suitable hydraulic model is the one provided under the name IRIS (TM), and still another is available from SINTEF of Trondheim, Norway. Any hydraulic model can be used in control system 90 according to the principles of this description.

A data collection and control interface 20 suitable for use as the data collection and control interface 94 in control system 90 are SENTRY (TM) and INSITE (TM) provided by Halliburton Energy Services, Inc. Any data collection interface and suitable d-.u data control can be used in the 90 control system

IMPI

MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY

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in accordance with the principles of this description.

Controller 96 operates to maintain a desired set pressure in the ring gear by controlling the operation of the sludge return regulator 34. When a desired updated circular crown pressure is transmitted from the data collection and control interface 94 to controller 96, the controller uses the desired pressure in the circular crown as a preset value and controls the operation of regulator 34 in a manner (for example, increasing or decreasing the resistance of the flow through the regulator as necessary) to maintain the preset pressure in the circular crown 20. Regulator 34 can be closed more to increase flow resistance, or open more to decrease flow resistance.

Maintaining the set pressure is accomplished by comparing the set pressure with a measured pressure in the circular crown (such as, the pressure detected by any of the sensors 36, 38, 40), and decreasing the flow resistance through of regulator 34 if the measured pressure is greater than the set pressure, and increase the flow resistance through the regulator if the measured pressure is less than the set pressure. Of course, if the set and measured pressures are equal, then no adjustment of the regulator 34 is required. This process oe

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C,,. ,,,. _ INDUSTRIAL preference is automated, so that no human intervention is required, although human intervention can be used if desired.

Controller 96 can also be used to control the operation of vertical pipeline flow control devices 76, 78 and bypass flow control device 74. Controller 96 can thus be used to automate the processes of diverting fluid flow 18 from riser 26 to diversion tubing 72 before making a connection to drill pipe 16, then diverting flow from the diversion pipe to the vertical pipe after the connection is made, and then resume normal circulation of drilling fluid 18. Again, no human intervention may be required in these automated processes, although human intervention may be used if desired, for example, to start each process, in turn, to manually operate a system component, etc.

Referring now further to FIG. 4, a schematic flow diagram is provided for a method 100 for making a connection of the drill pipe to the well drilling system 10 using the control system 90. Of course, the method

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100 can be used in other systems for pe'r ¥ S^r£^lto^Lcio? · '' wells, and with other control systemsοοηΤδΉηθ ^ ~ “ícs” principles of this description.

The process for connecting the drill pipe begins in step 102, in which the process begins. A drill pipe connection is typically made when the bore 12 has been drilled enough so that the drill pipe 16 must be elongated to drill further.

In step 104, the output of the flow quantity of the pump 68 can be decreased. By decreasing the magnitude of flow of fluid outlet 18 from the drum

68, it is more convenient to keep regulator 34 within its most effective operating variation (typically, between about 30% to about 70% of maximum aperture ';

during the connection process. However, this step is not necessary if, for example, the regulator 34 could otherwise remain within its effective operating range.

In step 106, the set pressure changes due to the reduced flow of fluid 18 (for example, to compensate for the decreased friction of the fluid in the ring gear 20 between bit 14 and wing valve 28 resulting in a circulation density reduced equivalent). the interface

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FROM THE FHÜ? ¡AGE S¿ ** ^ * 'w&gt; ^ * for obtaining and controlling data 94 receives example indications, from sensors 58, 60, 62, 66, 67) that the magnitude of fluid flow 18 has decreased, and the hydraulic model 92 in response determines that a changed pressure in the circular crown is desired to maintain the desired downhole pressure, and controller 96 uses the desired changed pressure in the circular crown as a preset value for control the operation of the regulator 34.

In a slightly overbalanced controlled pressure drilling operation, the preset pressure could probably increase, due to the reduced equivalent circulation density, in which case the flow resistance through regulator 34 could be increased in response. However, in some operations (such as,

<td>.ones</td><td>drilling</td><td>sub</td><td>-balanced</td><td colspan="2">in the setting</td>

<td>gas</td><td>or other fluid</td><td>of</td><td>light weight</td><td>to the</td><td>fluid of</td>

<td> 18</td><td>to decrease</td><td>the</td><td>pressure on</td><td>the</td><td>bottom of the</td>

<td colspan="3">set pressure could</td><td>decrease</td><td>(by</td><td>example,</td>

due to the production of liquid at the bottom of the well).

In step 108, the restriction to fluid flow 18 through regulator 34 is changed, due to the desired changed pressure in the circular crown in step 106. As discussed above, controller 96 controls the operation of regulator 34, in this case changing the

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flow restriction through the parS regulator^DJbb * terí ^ r ^ l¿r changed pressure set. Also, δδϊΛδ¹ I know ¹ previously, the set pressure could increase or decrease.

Concurrently performed steps 104, 106, and 108 are represented in the flow chart of Figure 4, because the set pressure and restriction of the sludge return regulator can vary continuously, either in response to each other, in response to the change in the mud pump output and in response to other conditions, as discussed above.

In step 109, the diversion flow control device 74 gradually opens. This gradually diverts an increasing proportion of the fluid 18 to flow through the bypass pipe 72, rather than through the vertical pipe 26.

In step 110, the set pressure changes due to the reduced flow of the fluid 18 through the drill pipe 16 (for example, to compensate for the decreased friction of the fluid in the circular crown 20 between the bit and the wing valve 28 giving resulting in an equivalent reduced density of circulation). The flow through the drill pipe 16 is substantially reduced when the bypass flow control device 74 is opened, because the bypass pipe 72 becomes the

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MEXICAN INSTITUTE OE LA FRÓPItPAO r- _Ί INDUSTRIAL fluva v, do

<img file="MX340331B_D0018.tif" />

path of least resistance so that the fluid 18 flows through the diversion line 72. The data acquisition and control interface 94 receives indications (for example, from sensors 58, 60, 62, 66, 67) that the magnitude of fluid flow 18 through drill pipe 16 and the ring gear has decreased, and the hydraulic model 92 in response determines that the changed pressure of the circular crown is desired to maintain the desired pressure at the bottom of the well, and controller 96 uses the desired pressure changed in the circular crown as a preset value to control the operation of regulator 34.

In a slightly overbalanced controlled pressure drilling operation, the set pressure could probably increase, due to the equivalent reduced circulation density, in which case the flow restriction through regulator 34 could be increased in response. However, in some operations (such as underbalanced drilling operations in which gas or other light weight fluid is added to drilling fluid 18 to decrease downhole pressure), the set pressure may decrease. (for example, due to the production of liquid at the bottom of the well).

In step 111, the flow restriction is changed

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INSTITUTO MEJ tCAMU Ot LA HIOfTEOAU of fluid 18 through regulator 34, due '^^υ51'έί^ι desired changed pr in the circular crown in 'fe! ......... pTSé' 1 i σΤ'Τ'ΰΤη'ό was previously analyzed, controller 96 controls the operation of regulator 34, in this case change the restriction to flow through the regulator to obtain the

<td>fixed pressure</td><td>changed. Too,</td><td>how</td><td>was analyzed</td>

<td>previously the</td><td>set pressure could</td><td colspan="2">increase or decrease.</td>

<td>At</td><td>Flowchart</td><td>of the</td><td>figure 4 is</td>

<td>represents that</td><td>steps 109, 110</td><td>and 111</td><td>will be made</td>

<td>concurrently,</td><td>because the</td><td>Pressure</td><td>fixed and the</td>

Regulator restriction for sludge return can vary continuously, either in response to each other, in response to the opening of the bypass flow control device 74, and in response to other conditions, as discussed above. However, these steps could be performed concurrently in other examples.

In step 112, the pressures in the vertical pipe 26 and the circular crown 20 at or near the surface (indicated by the sensors 36, 38, 40, 44) are equalized. At this point, the bypass flow control device 74 must be fully open, and substantially all of the fluid 18 is flowed through the bypass line 72, 75 and not through the vertical line 26 (because the diversion pipeline represents

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In step 114, the flow control device 81 of the vertical pipe is closed. The separate vertical pipeline bypass flow control device 78 must already be closed, in which case valve 76 could only be closed in step 114.

At step 116, a vertical pipeline discharge valve 82 (see Figure 10) could be opened to discharge pressure and fluids from vertical pipeline 26 in preparation for breaking the connection between the Kelley or top drive and drill pipe 16. At this point, riser 26 is vented into the atmosphere.

In step 118, the Kelley or top drive is disconnected from the drill pipe 16, another piece of drill pipe is connected to the drill pipe, and the Kelley or top drive is connected to the top of the drill pipe. drilling. This step is performed in accordance with conventional drilling practice, with at least one exception, as it is conventional in drilling practice to turn off the pumps.

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INÍTITJjTO JMtJSGlwro ZM1 * f * 0WI¡&gt; AD · ii. ,, „. iwwmji plumbing while a connection is being made however, in method 100, the plumbing pumps 68 preferably remain on, although the vertical line valve 76 is closed and all flow is diverted to manifold 32 to control pressure of the circular crown. Check valve 21 prevents flow upward through drill pipe 16, while a connection is being made with the sounding pumps 68 turned on.

In step 120, the discharge valve of the vertical pipe 82 is closed. The vertical pipe 26 is thus again isolated from the atmosphere, although the vertical pipe and the newly added piece of the drill pipe are practically empty. (ie not filled with fluid 18) and the pressure therein is at or near ambient pressure before connection is made.

In step 122, the vertical pipe diversion flow control device 78 is opened (in the case of the valve and the flow reducer configuration of Figure 1) or gradually opened (in the case of the configuration of the regulator in figure 2). In this way, the fluid 18 is allowed to fill the vertical pipe 26 and the newly added piece of the drill pipe, as indicated in step 124.

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126. However, it will continue to flow at this point. The

Over time, the pressure in the will equal the pressure in the surface circular crown, as indicated in the passage of virtually all of the fluid 18 through the diversion line 72 static pressure in the vertical line 26 should be substantially equalized with the pressure in pipes 30, 73, 75 upstream of regulator manifold 32.

At step 128, the flow control device of the vertical pipe 76 is opened in preparation for diverting the flow of the fluid 18 to the vertical pipe 26 and thereby through the perforation pipe 16. The flow control device bypass line 78 then closes. Note that by pre-filling the vertical pipe 26 and the perforation pipe 16, and equalizing the pressures between the vertical pipe and the circular crown 20, the step of opening the device for flow control of the vertical pipe 76 does not cause any transient significant undesirable pressure in the circular crown or pipes for mud return 30, 73. Virtually all fluid 18 will continue to flow through bypass line 72, rather than through vertical line 26, even if the vertical line flow control device 76 is opened.

<img file="MX340331B_D0022.tif" />

vertical pipe 76, 78 separately¹ · Β »Μ» '··· »η 3όΊο · flow control device for vertical pipe 81, then, the flow control device 81 gradually opens to slowly fill vertical pipe 26 and perforation pipe 16, and then fully opens when the pressures in the vertical pipe and the circular crown 20 are substantially equalized.

In step 130, the diversion flow control device 74 is gradually closed, thereby diverting an increasing proportion of the fluid 18 to flow through the vertical pipe 26 and the perforation pipe 16, instead of to through the diversion pipeline

72. During this step, the circulation of the fluid 18 begins through the drill pipe 16 and the bore 12.

At step 132, the set pressure changes due to the flow of fluid 18 through drill pipe 16 and circular crown 20 (for example, to compensate for increased fluid friction resulting in increased equivalent density of circulation) . Data acquisition and control interface 94 receives indications (eg, from sensors 60, 64, 66, 67) that the magnitude of fluid flow 18 through bore 12 has increased, and hydraulic model 92 in response determines

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FROM INDUSTRIAL IRROISIS, a changed pressure in the circular crown is desired to maintain the desired pressure at the bottom of the well, and controller 96 uses the desired changed pressure in the circular crown as a precise value to control the operation of the regulator 34. The desired pressure in the circular crown can either increase or decrease, as discussed above for steps 106 and 108.

In step 134, the restriction for fluid flow 18 through regulator 34 is changed, due to the desired changed pressure in the circular crown in step

132. As discussed above, controller 96 controls the operation of regulator 34, in this case by changing the flow restriction through the regulator to obtain the set changed pressure.

In the flow chart of Fig. 4, it is shown that steps 130, 132 and 134 are performed concurrently, because the set pressure and restriction of the sludge return regulator can vary continuously, either in response to each other, in response to closure of the diversion flow control device 74 and in response to other conditions, as discussed above.

In step 135, the output of the flow quantity from pump 68 can be increased in preparation

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INSTITUTO MEXICANO ΟΕ'_Α ??. Γ&gt; ί · ΙΕηΛΟ η π -,, „INDUSTRIAL, to resume drilling of borehole 12. This increased high flow maintains regulator 34 in its optimum variacTóñ of operation, although this step (like which with step 104 discussed above) may not be used if the regulator is otherwise maintained at its optimum operating variance.

At step 136, the set pressure changes due to the increased flow of fluid 18 (for example, to compensate for the increased friction of the fluid in the ring gear 20 between bit 14 and wing valve 28 resulting in increased equivalent density traffic). Data acquisition and control interface 94 receives indications (eg, from sensors 58, 60, 62, 66, 67) that the magnitude of fluid flow 18 has increased, and hydraulic model 92 in response determines that You want a changed pressure in the circular crown to maintain the desired downhole pressure, and controller 96 uses the desired changed pressure in the circular crown as a preset value to control the operation of regulator 34.

In a slightly overbalanced controlled pressure drilling operation, the set pressure could probably decrease, due to the increased equivalent circulation density, in which case the flow restriction through regulator 34 could be decreased by

<img file="MX340331B_D0025.tif" />

IMPI

MEXICAN INSTITUTE OE THE PROPERTY response. industrial

In step 137, the reaLiiutlun 'is changed to the fluid flow 18 through regulator 34, due to the desired pressure changed in the circular crown in step 136. As discussed above, controller 96 controls the operation of regulator 34, in this case changing the flow restriction through the regulator to obtain the set changed pressure. Also, as discussed above, the set pressure could increase or decrease.

In the flow chart of Figure 4, it is represented that steps 135, 136 and 137 will be performed concurrently, because the set pressure and the restriction of the sludge return regulator can vary continuously, either in response to each other, in response to the change in the mud pump output and in response to other conditions, as discussed above.

In step 138, drilling of probe 12 is resumed. When another connection is needed in drill pipe 16, steps 102 to 138 can be repeated.

In the flow chart of FIG. 4, steps 140 and 142 are included for connection method 100 to emphasize that control system 90 continues to operate throughout the method. That is, the interface for obtaining and controlling data 94 continues to receive the data.

<img file="MX340331B_D0026.tif" />

from sensors 36, 38, 40, 44, 46, 54,

66, 67 and supplies the appropriate data to the hiuraüTtetr-92 model. The hydraulic model 92 continues to determine the desired pressure in the circular crown corresponding to the desired pressure at the bottom of the well. Controller 96 continues to use the desired pressure in the ring gear as a set pressure to control the operation of regulator 34.

It will be appreciated that all or most of the steps described above can be conveniently automated using control system 90. For example, controller 96 can be used to control the operation of any or all flow control devices 34, 74 , 76, 78, 81 automatically in response to the input of the interface for obtaining and controlling data 94.

Preferably human intervention can be used to indicate to the control system 90 when it is desired to start the connection process (step 102), and then indicate when the connection of the perforation pipe has been made (step 118), although practically all other steps could be automated (eg, by properly programming the software elements of control system 90). However, it is envisaged that all steps 102 to 142 can be automated, for example, if a faith is used:

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Referring now further to Figure 5, another configuration of the control system 90 is representatively illustrated. The control system 90 of Figure 5 is very similar to the control system of Figure 3, although it differs at least in that they are included in the control system of FIG. 5 a predictive device 148 and a data validator 150.

Predictive device 148 preferably comprises one or more neural network models for predicting various parameters in the well. These parameters could include the outputs of any of the sensors 36, 38, 40,

44, 46, 54, 56, 58, 60, 62, 64, 66, 67, the preset pressure output on the circular crown from the hydraulic model 92, the positions of the flow control devices 34, 74, 76, 78, the density of drilling fluid 18, etc. By means of predictive device 148 any parameter in the well can be predicted, and any combination of parameters in the well.

Predictive device 148 is preferably ready to enter actual present and past values

INSTITUTO MEXICANO J for the parameters to the predictive device¹?^THE¿£ £ ^^ ernSffiréfe »# weights on the predictive device 14fr se - based on output derivatives of the predictive device with respect to the terms.

Predictive device 148 may be prepared to input data obtained during drilling to the predictive device, while making connections in drill pipe 16, and / or during other stages of a general drilling operation. Predictive device 148 may be prepared to enter data that is obtained while at least one pre-drill is being drilled into the predictive device.

Preparation may include inputting to predictive device 148 data indicative of past errors in predictions produced by the predictive device. Predictive device 148 may can be prepared by entering data generated by a computer simulation of the well drilling system 10 (including the drilling rig, the well, the equipment used, etc.).

Once prepared, the predictive device 148 can accurately predict or estimate what value one or more parameters should have in the present and / or future. Predicted parametric values ​​can be supplied to data validator 150 data validation.

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Predictive device 148 does not necessarily comprise one or more neural network models. Other types of predictive devices that can be used include an artificial intelligence device, an adaptive model, a generalizing nonlinear function for real systems, a genetic algorithm, a linear system model, and / or a nonlinear system model, combinations of these, etc.

Predictive device 148 can perform regression analysis, perform regression on a nonlinear function, and can use granular computation. An output of a first primary model may be input to predictive device 148 and / or a first primary model may be included in the predictive device.

Predictive device 148 receives the current parametric values ​​from data validator 150, which may include one or more digital programmable processors, memory, etc. The data validator 150 uses various pre-programmed algorithms to determine if the measurements of the sensors, the positions of the device for flow control, etc., received from the interface for obtaining and controlling data 94 are valid.

For example, if an acceptable current parametric value,

<img file="MX340331B_D0028.tif" />

received is out of a variation (for example, due to a sensor that is not working) or * · differs by more than a predetermined maximum amount from a predicted value for that parameter (for example, due to a malfunctioning sensor), then, data validator 150 may signal that the current parametric value will be invalid. Invalid parameter values ​​may not be used to prepare predictive device 148, or to determine the desired set pressure in the ring gear by hydraulic model 92. Valid parametric values ​​could be used to prepare predictive device 148, to update hydraulic model 92, to register to the interface database for data collection and control 94 and, in the case of the desired set pressure in the circular crown, transmitted to controller 96 to control the operation of flow control devices 34, 74, 76, 78.

The desired set pressure in the circular crown can be communicated from the hydraulic model 92 to each of the data collection and control interfaces 94, the predictive device 148 and the controller 96. The desired set pressure in the circular crown is communicated from the hydraulic model 92 towards the interface for obtaining and controlling data for registration in its database, and for

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retransmit the other current parametric values ​​to data validator 150.

The desired set pressure in the circular crown is communicated from hydraulic model 92 to predictive device 148 for use in predicting future preset values ​​for the circular crown. However, the predictive device 148 could receive the desired pressure preset value in the circular crown (along with the other current parametric values) from the data validator 150 in other examples.

The preset value of desired pressure in the circular crown is reported from hydraulic model 92 to controller 96 for use in the event of a malfunction of the data collection and control interface 94 or data validator 150, or otherwise Output from these other devices is not available. In those circumstances, controller 96 could continue to control the operations of the various flow control devices 34, 74, 76, 78 to maintain / achieve the desired pressure in the ring gear 20 near the surface.

Predictive device 148 is prepared in real time, and is capable of predicting the current values ​​of one or more sensor measurements based on the outputs of the

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DiV.FfcXTín.X »minus some of the other sensors. Thus*'^{TO THE} if '^ TTTa sensor output becomes unavailable, predictive device 148 may supply the missing sensor measurement values ​​to data validator 150, at least temporarily, until the sensor output is available again. If, for example, during the drilling pipe connection processes described above, one of the flow meters 62, 64, 66 malfunctions, or its output is otherwise unavailable or invalid, then the data validator 150 You can substitute the predicted flow meter output for the current flow meter output (or it does not exist). It is contemplated that, in current practice, only one or two of the flow meters 62, 64, 66 can be used. In this way, if the data validator 150 stops receiving the valid output from one of those flow meters, the determination of the proportions of the fluid 18 flowing through the vertical pipe 26 and the flow could no longer be carried out. deviation line 72, if not for the output of the parametric values ​​predicted by the predictive device 148. It will be appreciated that measurements of the proportions of the fluid 18 flowing through the vertical pipe 26 and the bypass pipe 72 are very useful, for example, in calculating the equivalent circulation density and / or the friction pressure by the

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MEXICAN INSTITUTE - I ·. '

FROM PROPERTY 'ζ ^ Μ ^^_β. &lt;· Hydraulic model 92 during the connection process of the drill pipe.

Validated parametric values ​​are reported from data validation device 150 to hydraulic model 92 and controller 96. Hydraulic system 92 uses validated parametric values, and possibly other data streams, to calculate the pressure currently present at the bottom of the well at the point of interest (for example, at the bottom of borehole 12, in a problem area , in a casing shoe, etc.), and the desired pressure in the circular crown 20 near the surface necessary to achieve a desired pressure at the bottom of the well.

The data validator 150 is programmed to examine the individual parametric values ​​received from the data collection and control interface 94 and determine if each falls within a predetermined variation of expected values. If the data validator 150 detects that one or more parametric values ​​received from the data collection and control interface 94 is invalid, it can send a signal to the predictive device 148 to stop the preparation of the neural network model for the faulty sensor, and stop the preparation of the other models that depend on the parametric values ​​from the sensor

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DEFECTIVE MEXICAN INSTITUTE OF THE PROP / EOAP to prepare. industrial

Although the predictive device148 piléde¹ By stopping the preparation of one or more neural network models when a sensor fails, it can continue to generate predictions for the sensor output or faulty sensors based on other sensor inputs that continue to operate towards the predictive device. By identifying a faulty sensor, data validation device 150 can substitute the predicted sensor parametric values ​​from predictive device 148 for controller 96 and hydraulic model 92.

Additionally, when the data validator 150 determines that a sensor has a malfunction or its output is not available, the data validation device may generate an alarm and / or a subsequent warning, identifying the sensor as malfunctioning, in such a way that an operator can take corrective action.

The predictive device 148 preferably is also capable of preparing a neural network model representing the output of the hydraulic model 92. A predicted value for the preset value of the desired pressure in the circular crown is communicated to the data validator 150. If the hydraulic model 92 has difficulties to generate adequate values ​​or is not available, the validation device

<img file="MX340331B_D0030.tif" />

IMPIfjs

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OF THE PROPERTY

INDUSTRIAL data 150 can substitute the preset value of the desired pressure in the circular crown with the 96 controller.

Referring now further to FIG. 6, an example of predictive device 148 is illustrated representatively, separate from the rest of control system 90. In this view, it can be seen that predictive device 148 includes a neural network model

152 outputting the predicted current values ​​(and_n) and / or futures (and_n+ i, and_n+ 2r · · ·) for a parameter y.

Various different current and / or past values ​​for parameters a, b, c, ... are entered into neural network model 152 to prepare the neural network model, to predict parametric and values, etc. The parameters a, b, c, ..., and, ... can be any of the sensor measurements, the positions of the device for flow control, the physical parameters (for example, mud weight, drilling depth, etc.), etc., described above.

Actual and / or predicted actual and / or past values ​​for parameter y can also be entered into the neural network model 152. Differences between actual and predicted values ​​for parameter y can be useful in preparing the network model. Neural 152 (for example, to minimize differences between current and predicted values).

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During preparation, weights are assigned¹*¹ to

<img file="MX340331B_D0031.tif" />

Various input parameters and these weights are automatically adjusted in such a way that differences between current and predicted parametric values ​​are minimized. If the fundamental structure of the neural network model 152 and the input parameters are selected appropriately, readiness could result in very little difference between current parametric values ​​and predicted parametric values ​​after an adequate setup time (and preferably short).

It may be useful for a single neural network model 152 to output the predicted parametric values ​​for only a single parameter. Multiple neural network models 152 can be used to predict values ​​for the respective multiple parameters. In this way, if one of the neural network models 152 fails, the others will not be affected.

However, efficient resource utilization could prevent a single neural network model 152 from being used to predict multiple parametric values. This configuration is representatively illustrated in Figure 7, in which the neural network model 152 outputs predicted values ​​for the multiple parameters w, x, y ...

If multiple neural networks are used, it is not necessary that all neural networks share the same

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tickets. In an example representatively illustrated in Figure 8, two neural network models 152 are used,

154. Neural network models 152, 154 share some of the same input parameters, although the model

152 it has some parameter input values ​​which model 154 does not share, and model 154 has parameter input values ​​that are not inputs to model 152.

If a neural network model 152 outputs predicted values ​​only for an individual parameter associated with a particular sensor (or other source for a current parametric value), then if the sensor (or other current parametric value source) fails, the Neural network model that predicts its output can be used to supply parametric values ​​while operations continue without interruption. Because the neural network model 152 in this situation is used only to predict the values ​​for a single parameter, the preparation of the neural network model can be conveniently stopped as soon as sensor failure (or other source of values) occurs. current parametric values), without affecting any of the other neural network models that are being used to predict other parametric values.

Referring now further to FIG. 9, another representative and schematic is illustrated

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MEXICAN INSTITUTE OF LA PLOMEO ·.!.

Figure 9 configuration is similar in most respects to Figure 2 configuration.

However, in the configuration of Figure 9, the 5 flow control device 78 and the flow reducer 80 are included with the flow control device 74 and the flow meter 64 in a flow diversion unit.

156 separately. Flow diversion unit 156 can be supplied as a helmet for convenient transportation and installation at a drilling rig site. Multiple regulator 32, pressure sensor, and flow meter 58 can also be provided as a separate unit.

Note that the use of flow meters 66,

67 it's optional. For example, the flow through the vertical pipe 26 can be deduced from the outlets of the flow meters 62, 64, and the flow through the sludge return pipe 73 can be deduced from the outlets of flow meters 58, 64.

Referring now further to FIG. 10, another configuration of the well-drilling system 10 is representative and schematically illustrated. In this configuration, the flow control device 76 is connected upstream of the vertical pipe distributor of the

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MUICAWO INSTITUTE D £ LA FAOFÍEPAD survey 70. This arrangement has certain benefits, such as, no modifications are needed to the riser 70 riser or the tubing between the manifold and the Kelley, the riser 82 riser discharge valve can be used to vent the riser as in normal drilling operations (there is no need to change the procedure for the drilling equipment, nor is there a need for a separate vent pipe from the unit to divert flow 156), etc.

Flow control device 76 may be interconnected between probing pump 68 and standpipe distributor 70 using, for example, snap fittings 84 (such as tap fittings, etc.). This will allow the flow control device 76 to be conveniently adapted for interconnection in various plumbing pump lines.

A fully adapted and specially adapted automated flow control device 76 (eg, automatically controlled by controller 96) can be used to control flow through riser 26, rather than using the conventional riser valve in a upright pipe distributor 70. The 81 Total Flow Control Device can be adapted to be used as described herein (for example, to control flow through the pipeline

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INSTITUTE ΜΕΧ_ | -A No. etc.), rather than for conventional drilling purposes.

It can now be fully appreciated that the foregoing description provides substantial improvements to the pressure and flow control technique in drilling operations. These improvements include the incorporation of the predictive device 148 and the data validator 150 in the system for pressure and flow control.

90, whereby sensor outputs and hydraulic model 92 can be supplied, even if these sensor outputs and / or hydraulic models become unavailable during a drilling operation.

The foregoing description provides a well drilling system 10 for use with a pump 68 that pumps drilling fluid 18 through a drill pipe 16, during drilling of a bore 12. A flow control device 81 regulates the flow from the pump 68 into the drill pipe 16, with the flow control device 81 that will interconnect between the pump 68 and a vertical pipe distributor of the bore 70. Another device to control

INSTITUTO MEXICANO Dí LA EMOneCAP flow 74 regulates the flow from the pump * ® #^rwñ.^lacicr-mía pipe 75 in communication with a circular crown 20 formed between drill pipe 16 and bore 12. Flow is allowed simultaneously through flow control devices 74, 81.

Flow control device 81 can be operated independently of the operation of flow control device 74.

Pump 68 may be a drilling mud pump in communication via flow control device 81 with riser 26 to supply drilling fluid 18 into drill pipe 16. System 10 is preferably free of any other pumps that apply pressure to the circular crown

20.

System 10 may also include another flow control device 34 that variably restricts flow from circular crown 20.

An automated control system 90 can control the operation of the flow control devices 34, 74 to maintain a desired pressure in the circular crown while making a connection in the drill pipe 16. The control system 90 can also control device operation operation f JL Ρ I

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for flow control 81 to maintain presic^li’^lJST2lAl'' the circular crown while connection is being made '' '' - drill pipe 16.

The above description also describes a method of maintaining a desired downhole pressure during a well drilling operation. The method includes the steps of: dividing the flow of drilling fluid 18 between a pipe 26 in communication with the interior of a drill pipe 16 and a pipe 75 in communication with a circular crown 20 formed between the drill pipe 16 and a bore 12, the splitting passage flow system including allowing flow through a vertical pipeline flow control device 81 interconnected between a pump 68 and a vertical pipeline distributor 70, the vertical pipe distributor 70 will be interconnected between the vertical pipe flow control device 81 and the drill pipe

16.

The flow division step may also include allowing flow through a bypass flow control device 74 interconnected between pump 68 and circular crown 20, while allowing flow through the flow control device of the standpipe 81.

The method also includes the step of closing the

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IMPI Mexican institute OF PROPERTY device for control of pipe flow^IN!W ¥^,faith after equalizing the pressures in the rnb'é'llcl¹ 20 err communication with the interior of the drill pipe 16 and pipe 75 in communication with the circular crown 20.

The method may include the steps of: making a connection to the drill pipe 16 after the step of closing the vertical pipe flow control device 81, then allowing a flow through the vertical pipe flow control device 81 while flow is allowed through the bypass flow control device 74; and then closing the diversion flow control device 74 after the pressures are again equalized in the pipe 26 in communication with the interior of the drill pipe 16 and in the pipe in communication with the circular crown 20.

The method also includes the step of allowing a flow through another flow control device (for example, a regulator 34) continuously during the division of flows, closing the device for flow control of the vertical pipe, making a connection and closing steps of the deviation flow control device, thereby maintaining a desired pressure in the circular crown corresponding to the desired downhole pressure.

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The method also includes the step of determining the desired pressure in the circular crown in response to input of sensor measurements to a hydraulic model 92 during drilling operation. The step of maintaining the desired pressure in the circular crown may include automatically varying the flow through the flow control device (eg, a regulator 34) in response to comparing a pressure measured in the circular crown with the desired pressure. in the circular crown.

The above description also describes a method

100 to make a connection in a drill pipe

16, while maintaining a desired pressure at the bottom of the well. Method 100 includes the steps of:

pumping a drilling fluid 18 from a drilling mud pump 68 and through a sludge return regulator 34 during method 100 to make the full connection;

determining a desired pressure in the circular crown that corresponds to the desired pressure at the bottom of the well during method 100 to make the full connection, the circular crown 20 to be formed between drill pipe 16 and a bore 12;

regulate the flow of drilling fluid 18 through the sludge return regulator 34, maintaining autXnüM with this the desired pressure in the circular crown / 'ífG ^ nteM ^ l ^ method 100 to make the total connection;

increase the flow through a diversion flow control device 74 and decrease the flow through a vertical pipe flow control device 81 interconnected between the drilling mud pump 68 and a vertical drilling pipe distributor 70, thereby diverting at least a portion of the drilling fluid flow from a pipe 26 in communication with an interior of the drill pipe 16 to a pipe 75 in communication with the circular crown 20;

prevent flow through the vertical pipe flow control device 81;

then make the connection in the drill pipe 16, and then decrease the flow through the bypass flow control device 74 and increase the flow through the vertical pipe flow control device 81, thereby diverting at least another portion of the flow of the drilling fluid to the pipe 26 in communication with the interior of the drilling pipe 16 from the pipe 75 in communication with the circular ring 20.

The steps of increasing flow through the bypass flow control device 74 and ⁵³ IMPI

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simultaneously permit flow through the vertical pipe diversion flow control devices 74, 81.

The steps for decreasing flow through the diversion flow control device 74 and increasing flow through the vertical pipe flow control device 81 further comprise simultaneously allowing flow through the flow control devices vertical pipe diversion flow 74, 81.

The method 100 may also include the step of equalizing the pressure between the line 26 in communication with the interior of the drilling line 16 and the line 7 5 in communication with the circular ring 20. This pressure equalizing step is preferably performed after the step of increasing the flow through the bypass flow control device 74, and before the step of decreasing the flow through the vertical pipeline flow control device 81.

Method 100 also includes the step of equalizing the pressure between line 26 in communication with the interior of the drill line 16 and line 75 in communication with the circular crown 20. This step of

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<img file="MX340331B_D0036.tif" />

Pressure equalization is preferably performed after the step of decreasing flow through the bypass flow control device 74, and before the step of increasing flow through the vertical tube flow control device 81.

The step in determining the desired pressure in the circular crown may include determining the desired pressure in the circular crown in response to the input of sensor measurements to a hydraulic model 92. The step of maintaining the desired pressure in the circular crown may include varying automatically flow through the regulator to return the sludge 34 in response to comparing a measured pressure in the circular crown with the desired pressure in the circular crown.

The steps to decrease the flow through the vertical pipe flow control device 81, preventing a flow through the vertical pipe flow control device 81 and to increase the flow through the vertical flow control device riser 81 can be automatically controlled by a controller 96.

It should be understood that the various modalities of the present disclosure described herein can be used in various orientations, such as inclined,

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IMPI

MEXICAN INSTITUTE

OF PROPERTY V% '^J inverted, horizontal, vertical, etc., and '^? ¥^STIÍPiveí configurations, without departing from the principles 3e ”” * Ta * · present description. The modalities are simply described as examples of useful applications of the principles of description, which are not limited to any of the specific details of those modalities.

In the foregoing description of representative embodiments of this disclosure, directional terms, such as above, below, above, below, etc., are used for convenience to refer to the accompanying drawings. In general, above, top, up, and the like refer to a direction to the earth's surface throughout a borehole, and below, bottom, down, and the like refer to a direction away from the Earth's surface throughout the borehole.

Of course, someone skilled in the art could, with careful consideration of the foregoing description and representative modalities of the description, readily appreciate that many modifications, additions, substitutions, deletions, and other changes can be made to the specific modalities, and These changes are contemplated by the principles of the present description.

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Accordingly, the foregoing detailed description should be clearly understood to be provided by way of illustration and example only, the spirit and scope of the present invention will be limited only by the appended claims and their equivalents.

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