US20060289156A1 - Lateral control system - Google Patents
Lateral control system Download PDFInfo
- Publication number
- US20060289156A1 US20060289156A1 US11/408,635 US40863506A US2006289156A1 US 20060289156 A1 US20060289156 A1 US 20060289156A1 US 40863506 A US40863506 A US 40863506A US 2006289156 A1 US2006289156 A1 US 2006289156A1
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- Prior art keywords
- module
- monitoring
- lateral
- bore
- control
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- 238000012544 monitoring process Methods 0.000 claims abstract description 55
- 238000000034 method Methods 0.000 claims abstract description 8
- 238000004891 communication Methods 0.000 claims abstract description 7
- 239000012530 fluid Substances 0.000 claims description 7
- 239000000835 fiber Substances 0.000 claims 2
- 239000000126 substance Substances 0.000 claims 1
- 230000008901 benefit Effects 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 230000004888 barrier function Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 238000009434 installation Methods 0.000 description 2
- 210000002445 nipple Anatomy 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 238000011109 contamination Methods 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 125000001183 hydrocarbyl group Chemical group 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000008439 repair process Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
Definitions
- Multilateral wellbores are advantageous because they, by definition, access different areas of a hydrocarbon bearing formation from a single surface location. This is desirable from a cost standpoint for capital expenditure as well as having a much lesser impact on the surface environment.
- One of the problems associated with current monitoring and control schemes is that a large number of devices may need to be pulled from the well if entry to a more downhole portion of the well is required. Alternatively, entry may be had to remote portion of the well by using a device small enough to be run through the completion tubing but such devices are inherently small in size. In some cases, devices small enough to be run through the completion string are insufficient desirably address whatever issue prompted the run.
- the system includes at least one splitter having a lateral bore and a main bore, at least one control line at the splitter and at least one of a choke module, monitoring module, flow venturi module, and a control module disposed in operable communication with the lateral bore and outside of the main bore.
- FIG. 1 is a perspective partial cutaway view of a stackable splitter portion of the system disclosed herein with two auxiliary ports for monitoring and controlling modules;
- FIG. 2 is a schematic view of a leg and an auxiliary bore that is parameter transmissively connected
- FIG. 3 is a schematic view of a leg and an auxiliary bore that is fluid transmissively connected.
- the lateral control and monitoring system 10 comprises a stackable splitter 12 having an uphole main bore 14 , a downhole main leg 16 , and a downhole lateral leg 18 .
- the splitter may be embodied as a casing segment or tubing segment. Where the splitter is a casing segment, it is cementable in the hole. It is important to note that the concept hereof provides for one or more of control (decision-type control or flow-type control) and monitoring of a lateral leg of the splitter while leaving the main leg of the splitter (and hence the junction itself) fully open.
- control and/or monitoring modules are to be placed so as to interact with a target lateral (or potentially monitor parameters of the main bore) but not occlude the main bore. Thereby, greater access and tighter controls simultaneously with easier maintenance, repair or replacement of components is achieved.
- components are located directly in the lateral. For example, a choke intended to control flow from a particular lateral or a flow venturi intended to measure flow from or to a particular lateral would be positioned in that lateral.
- the connective opening (interface 40 ) is free of a barrier and so in addition to being transmissive to parameters such as temperature and pressure it is also fluid transmissive. It is noted however that each of the devices utilized for a particular application could be placed in the lateral and no ancillary bore provided while remaining in keeping with the unifying principle of this disclosure, which is to maintain the patency of the main bore. In applications utilizing one or more ancillary bores, referring to FIG. 1 , the ancillary bores 20 , 22 are located in what would otherwise be dead space in a splitter.
- the ancillary bore(s) 20 , 22 are configured to provide signal transmitting capability to other well components including intelligent components, such as monitors, controllers, sensors, etc. and control components such as chokes and other downhole tools. Moreover the ancillary bore(s) may be configured to receive a controller configured to communicate with multiple addressable devices or individual control and monitoring modules. In the event two ancillary bores are provided as illustrated, it is to be understood that they need not both be used. Indeed neither of the bores need be used.
- the device(s) may be, as noted above, a controller module, a monitoring module, an adjustable choke 24 , a venturi, a combination of the foregoing or other downhole tools. These are installed in leg 18 to control flow between lateral leg 18 and the main bore. These can alternatively be installed in ancillary bores as noted above, in which case, not only will they not impede access down the main bore, but they also will not impede access down the lateral bore. Modules 30 , 32 if used, may be installed with such tools as a diverter or kick over tool to replace one or both dummys. It should be noted that the splitter could be configured to accept two or more modules in a single module receptacle, if desired.
- the choke 24 which may be an adjustable choke and in one embodiment is variable from fully open to fully closed (thereby shutting off the lateral), is configured to land and be retained in lateral leg 18 .
- Choke 24 is also retrievable.
- the configuration in one embodiment employs a profile (see FIG. 2 ) 26 at an uphole end 28 of lateral leg 18 to receive choke 24 .
- Choke 24 may be installed at any time in the well construction program.
- the profile 26 comprises, in one embodiment, an existing nipple configuration such as for example that utilized in Baker Oil Tools Product Number H80185, a Model AF Seating Nipple.
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics And Detection Of Objects (AREA)
- Pipeline Systems (AREA)
Abstract
Disclosed herein is a lateral monitoring and/or control system. The system includes at least one splitter having a lateral bore and a main bore, at least one control line at the splitter and at least one of a choke module, monitoring module, flow venturi module and a control module disposed in operable communication with the lateral bore and outside of the main bore. Further disclosed herein is a method for controlling and/or monitoring of a multi-lateral well system. The method includes installing one or more splitter in a borehole, installing at least one control line to communicate remotely with each of the one or more splitters selectively communicating with one or more of at least one of a monitoring module, control module, choke module and flow venturi module.
Description
- This application claims the benefit of U.S. Provisional Application No. 60/673,529 filed Apr. 21, 2005, the contents of which are incorporated by reference herein in their entirety.
- In the hydrocarbon industry it is becoming more and more common to employ multiple branches known as laterals from a main leg of a wellbore. Wells having this characteristic are known as multilateral wellbores. Multilateral wellbores are advantageous because they, by definition, access different areas of a hydrocarbon bearing formation from a single surface location. This is desirable from a cost standpoint for capital expenditure as well as having a much lesser impact on the surface environment.
- Important with respect to multilateral wellbores is control and/or monitoring of fluids produced. It is desirable to monitor produced fluids to optimize production or so that action might be taken to avoid contamination of the well due to, for example, early water breakthrough in one of the laterals.
- One of the problems associated with current monitoring and control schemes is that a large number of devices may need to be pulled from the well if entry to a more downhole portion of the well is required. Alternatively, entry may be had to remote portion of the well by using a device small enough to be run through the completion tubing but such devices are inherently small in size. In some cases, devices small enough to be run through the completion string are insufficient desirably address whatever issue prompted the run.
- Disclosed herein is a lateral monitoring and/or control system. The system includes at least one splitter having a lateral bore and a main bore, at least one control line at the splitter and at least one of a choke module, monitoring module, flow venturi module, and a control module disposed in operable communication with the lateral bore and outside of the main bore.
- Further disclosed herein is a method for controlling and/or monitoring of a multi-lateral well system. The method includes installing one or more splitter in a borehole, installing at least one control line to communicate remotely with each of the one or more splitters selectively communicating with one or more of at least one of a monitoring module, control module, choke module and flow venturi module.
- Referring now to the drawings wherein like elements are numbered alike in the several Figures:
-
FIG. 1 is a perspective partial cutaway view of a stackable splitter portion of the system disclosed herein with two auxiliary ports for monitoring and controlling modules; -
FIG. 2 is a schematic view of a leg and an auxiliary bore that is parameter transmissively connected; and -
FIG. 3 is a schematic view of a leg and an auxiliary bore that is fluid transmissively connected. - Referring to
FIGS. 1 and 3 , the lateral control and monitoring system 10 comprises astackable splitter 12 having an upholemain bore 14, a downholemain leg 16, and a downholelateral leg 18. The splitter may be embodied as a casing segment or tubing segment. Where the splitter is a casing segment, it is cementable in the hole. It is important to note that the concept hereof provides for one or more of control (decision-type control or flow-type control) and monitoring of a lateral leg of the splitter while leaving the main leg of the splitter (and hence the junction itself) fully open. The method for providing such control/monitoring while leaving the main bore open can be practiced using the splitter illustrated herein either with ancillary bores (described hereunder) or without the ancillary bores, the overriding consideration being the leaving of the main bore patent so that access to laterals and their controls can be gained without pulling a large number of completion string components from the main bore simply to “get to the lateral”. There are clear benefits to arrangements facilitating the ability to reach target laterals from uphole without pulling monitoring or control modules from uphole splitters to gain access thereto. Further, one embodiment the disclosed splitter further provides for a location (which would otherwise be unused space) in which to place components of a downhole system and from which location (referred to herein as the “ancillary bore(s)”) the installed components are retrievable. Since in this embodiment too, the main bore is left open, access to individual control or monitoring modules whether in the lateral leg or in the ancillary bore of splitters that are farther downhole than the subject splitter does not require removal of such components from splitters farther uphole than the subject splitter. - The concept hereof provides for arrangement of modules and control lines in different configurations for different applications all of which maintain an open main bore. This can be in a tubing string and/or a casing string in different systems with differing overall properties. As noted above, control and/or monitoring modules are to be placed so as to interact with a target lateral (or potentially monitor parameters of the main bore) but not occlude the main bore. Thereby, greater access and tighter controls simultaneously with easier maintenance, repair or replacement of components is achieved. In some of the embodiments, components are located directly in the lateral. For example, a choke intended to control flow from a particular lateral or a flow venturi intended to measure flow from or to a particular lateral would be positioned in that lateral. A monitoring or control system however might be located in an ancillary bore and merely have sensors located in the lateral, or may simply have sensors exposed to the lateral (or the main bore) while not being directly in the lateral (or main bore). More particularly (see
FIGS. 2 and 3 ), ancillary bores may be configured with a parameter transmissive interface 40 (temperature, pressure, etc.) or fluidtransmissive interface 42 providing for communication with the lateral bore, main bore, or both. In one example a connective opening (interface 40) between the ancillary bore and lateral bore or main bore includes aflexible barrier 44 therein and as such is not fluid transmissive but is parameter transmissive. In another example (FIG. 3 ), the connective opening (interface 40) is free of a barrier and so in addition to being transmissive to parameters such as temperature and pressure it is also fluid transmissive. It is noted however that each of the devices utilized for a particular application could be placed in the lateral and no ancillary bore provided while remaining in keeping with the unifying principle of this disclosure, which is to maintain the patency of the main bore. In applications utilizing one or more ancillary bores, referring toFIG. 1 , theancillary bores lateral leg 18 andmain leg 16. The ancillary bore(s) 20, 22 are configured to provide signal transmitting capability to other well components including intelligent components, such as monitors, controllers, sensors, etc. and control components such as chokes and other downhole tools. Moreover the ancillary bore(s) may be configured to receive a controller configured to communicate with multiple addressable devices or individual control and monitoring modules. In the event two ancillary bores are provided as illustrated, it is to be understood that they need not both be used. Indeed neither of the bores need be used. They may stay plugged with, for example, dummy modules, indefinitely. One or both may be employed at will for monitoring, control or combination equipment. In the prior art this would have been unused space and is beneficially utilized according hereto to house control and/or monitoring modules(s) 30, 32 in a retrievable manner. Such control andmonitoring modules - Whether or not ancillary bores are utilized, the disclosure hereof specifically facilitates well control and monitoring control. These can be done alone or in combination. With these two concepts in place, any well configuration is handleable. Where multiple splitters are stacked, flows come from several different regions of a host formation, through lateral bores that extend thereinto. Because of the configuration taught herein, all of these flows are quantified, which then provides a true picture of one condition in the entire well. Where it is known, as in the system of this disclosure, (through monitor, control or both) what condition is prevailing at each of the laterals of a well the condition of the entire well must necessarily be known because it is the sum of its parts. In some embodiments hereof, each downhole control unit installed is addressable so that fewer or even one control line need be installed to communicate with one or more control and/or monitoring units or modules downhole.
- Installation of the described device includes running the
splitter 12 and cementing it in the wellbore (if a casing segment). If the particular splitter includes ancillary bore(s),dummy modules 30, 32 (as shown) may be installed therein to prevent debris from entering the ancillary bore(s), which might otherwise present difficulties with respect to installation of modules. A straddle wiper plug (not shown), as known in the art, may be employed to prevent cement entrance to profiles in the splitter if the splitter is a casing segment and intended to be cemented in place. In the casing splitter embodiment, once thesplitter 12 is at depth it is cemented in place. A lateral bore may be drilled and lined, etc. and suitable device(s) installed. The device(s) may be, as noted above, a controller module, a monitoring module, an adjustable choke 24, a venturi, a combination of the foregoing or other downhole tools. These are installed inleg 18 to control flow betweenlateral leg 18 and the main bore. These can alternatively be installed in ancillary bores as noted above, in which case, not only will they not impede access down the main bore, but they also will not impede access down the lateral bore.Modules - A very significant advantage of this system is that access to more downhole laterals of the well may be had without the need to remove devices connected with more uphole laterals.
- The choke 24, which may be an adjustable choke and in one embodiment is variable from fully open to fully closed (thereby shutting off the lateral), is configured to land and be retained in
lateral leg 18. Choke 24 is also retrievable. The configuration, in one embodiment employs a profile (seeFIG. 2 ) 26 at an uphole end 28 oflateral leg 18 to receive choke 24. Choke 24 may be installed at any time in the well construction program. Theprofile 26 comprises, in one embodiment, an existing nipple configuration such as for example that utilized in Baker Oil Tools Product Number H80185, a Model AF Seating Nipple. - While preferred embodiments have been shown and described, modifications and substitutions may be made thereto without departing from the spirit and scope of the invention. Accordingly, it is to be understood that the present invention has been described by way of illustrations and not limitation.
Claims (21)
1. A lateral monitoring and/or control system comprising:
at least one splitter having a lateral bore and a main bore;
at least one control line at the splitter; and
at least one of a choke module, monitoring module flow venturi module and a control module disposed in operable communication with the lateral bore and outside of the main bore.
2. A lateral monitoring and/or control system as claimed in claim 1 wherein the splitter further includes at least one ancillary bore.
3. A lateral monitoring and/or control system as claimed in claim 2 wherein at least one of the monitoring module and control module is disposed at the at least one ancillary bore.
4. A lateral monitoring and/or control system as claimed in claim 2 wherein the choke module or flow venturi module is disposed in the lateral bore and at least one of the monitoring module and the control module is disposed at the at least one ancillary bore.
5. A lateral monitoring and/or control system as claimed in claim 4 wherein the at least one ancillary bore is two ancillary bores.
6. A lateral monitoring and/or control system as claimed in claim 4 wherein the choke module or flow venturi module is disposed in the lateral bore and at least one of the monitoring module and the control module is disposed at one of the two ancillary bores.
7. A lateral monitoring and/or control system as claimed in claim 6 wherein the other of the monitoring module and the control module is disposed at the other of the two ancillary bores.
8. A lateral monitoring and/or control system as claimed in claim 2 wherein the at least one ancillary bore includes a pressure transmissive connection to at least one of the lateral bore and the main bore.
9. A lateral monitoring and/or control system as claimed in claim 8 wherein the pressure transmissive connection is a fluid transmissive connection.
10. A lateral monitoring and/or control system as claimed in claim 1 wherein the monitoring module monitors at least one of pressure, flow, temperature, chemical constituency and flow direction.
11. A lateral monitoring and/or control system as claimed in claim 1 wherein the splitter includes two ancillary bores each having at least one of the monitoring module and the control module and the lateral leg containing the choke module or the flow venturi module.
12. A lateral monitoring and/or control system as claimed in claim 1 wherein the choke module is remotely adjustable with respect to flow therethrough.
13. A lateral monitoring and/or control system as claimed in claim 1 wherein the system further comprises at least one control line accessing the at least one splitter.
14. A lateral monitoring and/or control system as claimed in claim 13 wherein the control line accesses a plurality of splitters.
15. A lateral monitoring and/or control system as claimed in claim 13 wherein the control line is at least one of fiber optic based, hydraulic based and electric based.
16. A lateral monitoring and/or control system as claimed in claim 14 wherein the control line is at least one of fiber optic based, hydraulic based and electric based.
17. A lateral monitoring and/or control system as claimed in claim 13 wherein the control line accesses each lateral bore and is disposed outside of the at least one splitter.
18. A lateral monitoring and/or control system as claimed in claim 13 wherein the control line is in operable communication with a plurality of addressable modules in a plurality of splitters for selective communication with such modules.
19. A lateral monitoring and/or control system as claimed in claim 2 wherein the at least one ancillary bore contains a dummy module to protect the at least one ancillary bore.
20. A method for controlling and/or monitoring of a multi-lateral well system comprising:
installing one or more splitters in a borehole;
installing at least one control line to communicate remotely with each of the one or more splitters; and
selectively communicating with one or more of at least one of a monitoring module, a control module, a choke module and a flow venturi module.
21. The method for controlling and/or monitoring of a multi-lateral well system as claimed in claim 20 wherein the method further includes installing at least one of said at least one of a monitoring module, a control module, a choke module and a flow venturi module in a position outside a main bore of the one or more splitters.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US11/408,635 US20060289156A1 (en) | 2005-04-21 | 2006-04-21 | Lateral control system |
Applications Claiming Priority (2)
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US67352905P | 2005-04-21 | 2005-04-21 | |
US11/408,635 US20060289156A1 (en) | 2005-04-21 | 2006-04-21 | Lateral control system |
Publications (1)
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US20060289156A1 true US20060289156A1 (en) | 2006-12-28 |
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Family Applications (1)
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US11/408,635 Abandoned US20060289156A1 (en) | 2005-04-21 | 2006-04-21 | Lateral control system |
Country Status (6)
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US (1) | US20060289156A1 (en) |
AU (1) | AU2006239959A1 (en) |
CA (1) | CA2610369A1 (en) |
GB (1) | GB2441079A (en) |
NO (1) | NO20075964L (en) |
WO (1) | WO2006116093A1 (en) |
Cited By (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20110186291A1 (en) * | 2010-02-04 | 2011-08-04 | Loc Lang | Methods and systems for orienting in a bore |
US20110226467A1 (en) * | 2010-03-18 | 2011-09-22 | Neil Hepburn | Well assembly with a composite fiber sleeve for an opening |
US8371368B2 (en) | 2010-03-31 | 2013-02-12 | Halliburton Energy Services, Inc. | Well assembly with a millable member in an opening |
WO2013112232A1 (en) * | 2012-01-25 | 2013-08-01 | Baker Hughes Incorporated | System and method for treatment of well completion equipment |
US8505621B2 (en) | 2010-03-30 | 2013-08-13 | Halliburton Energy Services, Inc. | Well assembly with recesses facilitating branch wellbore creation |
US9222896B2 (en) | 2012-09-14 | 2015-12-29 | Halliburton Energy Services, Inc. | Systems and methods for inspecting and monitoring a pipeline |
US9234613B2 (en) | 2010-05-28 | 2016-01-12 | Halliburton Energy Services, Inc. | Well assembly coupling |
WO2016010531A1 (en) * | 2014-07-16 | 2016-01-21 | Halliburton Energy Services, Inc. | Multilateral junction with mechanical stiffeners |
US10344570B2 (en) | 2014-09-17 | 2019-07-09 | Halliburton Energy Services, Inc. | Completion deflector for intelligent completion of well |
US10472933B2 (en) | 2014-07-10 | 2019-11-12 | Halliburton Energy Services, Inc. | Multilateral junction fitting for intelligent completion of well |
WO2020112594A1 (en) * | 2018-11-30 | 2020-06-04 | Halliburton Energy Services, Inc. | Multilateral junction with integral flow control |
US11371322B2 (en) | 2017-09-19 | 2022-06-28 | Halliburton Energy Services, Inc. | Energy transfer mechanism for a junction assembly to communicate with a lateral completion assembly |
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2006
- 2006-04-21 AU AU2006239959A patent/AU2006239959A1/en not_active Abandoned
- 2006-04-21 GB GB0722787A patent/GB2441079A/en not_active Withdrawn
- 2006-04-21 CA CA002610369A patent/CA2610369A1/en not_active Abandoned
- 2006-04-21 WO PCT/US2006/015102 patent/WO2006116093A1/en active Application Filing
- 2006-04-21 US US11/408,635 patent/US20060289156A1/en not_active Abandoned
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2007
- 2007-11-21 NO NO20075964A patent/NO20075964L/en not_active Application Discontinuation
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Cited By (22)
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Also Published As
Publication number | Publication date |
---|---|
GB0722787D0 (en) | 2008-01-02 |
AU2006239959A1 (en) | 2006-11-02 |
GB2441079A (en) | 2008-02-20 |
CA2610369A1 (en) | 2006-11-02 |
NO20075964L (en) | 2008-01-15 |
WO2006116093A1 (en) | 2006-11-02 |
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