US20110192596A1 - Through tubing intelligent completion system and method with connection - Google Patents
Through tubing intelligent completion system and method with connection Download PDFInfo
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- US20110192596A1 US20110192596A1 US13/021,744 US201113021744A US2011192596A1 US 20110192596 A1 US20110192596 A1 US 20110192596A1 US 201113021744 A US201113021744 A US 201113021744A US 2011192596 A1 US2011192596 A1 US 2011192596A1
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- 238000004519 manufacturing process Methods 0.000 claims abstract description 64
- 238000004891 communication Methods 0.000 claims description 57
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- 238000010168 coupling process Methods 0.000 claims description 13
- 238000005859 coupling reaction Methods 0.000 claims description 13
- 238000005553 drilling Methods 0.000 claims description 10
- 241000704611 Fig cryptic virus Species 0.000 description 9
- 238000003944 fast scan cyclic voltammetry Methods 0.000 description 9
- 239000012530 fluid Substances 0.000 description 9
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- 230000004048 modification Effects 0.000 description 4
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- 239000003129 oil well Substances 0.000 description 2
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- 230000015572 biosynthetic process Effects 0.000 description 1
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/028—Electrical or electro-magnetic connections
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
Definitions
- the secondary leg may be drilled in the same well to a new pocket of oil and/or gas.
- the secondary leg may be referred to as a lateral or multi-lateral leg. This process of drilling a lateral leg is required in order to rejuvenate a producing oil well without the considerable costs and expense of drilling a completely new well.
- FIG. 11 is a schematic illustration of communication coils employed in the wireless communications link illustrated in FIG. 10 , according to an embodiment of the disclosure.
- the corresponding coil 134 of the coil arrangement 130 may be provided at the lower end of a section of production tubing 136 that extends to the surface.
- production tubing 136 may have the same diameter as production tubing 50 .
- An opening 138 may be provided through the sidewall of production tubing 136 , similar to opening 54 , just above the corresponding coil 134 so that production fluid may flow around the corresponding coil arrangement 130 (from the annulus within the larger production tubing 30 and back into the interior of the smaller diameter section of production tubing 136 ).
- FIG. 10 another embodiment of a through tubing completion system 20 is illustrated.
- the through tubing completion system 20 shown may be similar to the through tubing completion system 20 described with respect to FIG. 8 . Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail.
Abstract
A technique facilitates use of a through tubing completion system run in a lateral borehole. The through tubing completion may comprise production tubing coupled to a flow control valve and one or more sensors measuring at least one characteristic of the lateral borehole. The through tubing completion also comprises a connection system which facilitates the transfer of signals between the through tubing completion extending into the lateral borehole and a surface location or other location.
Description
- The present document is based on and claims priority to U.S. Provisional Application Ser. No. 61/302,138, filed Feb. 7, 2010; to U.S. Provisional Application Ser. No. 61/302,137, filed Feb. 7, 2010; and to U.S. Provisional Application Ser. No. 61/302,232, filed Feb. 8, 2010.
- 1. Field of the Invention
- The present invention relates generally to well completion systems, and more particularly to through tubing intelligent completion systems. However, identification of an exemplary field is for the purpose of simplifying the detailed description and should not be construed as a limitation. Various embodiments of the concepts presented herein may be applied to a wide range of applications and fields as appropriate.
- 2. Description of the Related Art
- The following descriptions and examples are not admitted to be prior art by virtue of their inclusion in this section.
- When an existing oil well begins to become depleted or water out, there exists a need to close off or choke off the formerly producing formation and drill a secondary leg. The secondary leg may be drilled in the same well to a new pocket of oil and/or gas. Generally, the secondary leg may be referred to as a lateral or multi-lateral leg. This process of drilling a lateral leg is required in order to rejuvenate a producing oil well without the considerable costs and expense of drilling a completely new well.
- Often, these new lateral legs are drilled while the existing completion string remains in place. This type of drilling may be referred to as through tubing drilling or coiled tubing drilling. Through tubing drilling creates new drainage points in laterals or a series of laterals, often called multi-laterals. With this type of well construction, there are challenges with respect to completing these new drainage points due to the constraints posed by the existing upper completion sections. The existing upper completion sections generally reduce the through hole diameter of the well system available to run a through tubing completion. Additionally, another challenge is communicating with the through tubing completion in order to achieve selective control and data measurement. Of course, other challenges exist beyond these listed examples and may be addressed by this disclosure.
- Embodiments of the claimed system or methodology may comprise a through tubing completion system run in a lateral borehole. The through tubing completion may comprise production tubing coupled to a flow control valve and one or more sensors measuring at least one characteristic of the lateral borehole. In addition, the through tubing completion may comprise one of a male or female wet connect system configured to communicatively couple with the flow control valve and the one or more sensors. A corresponding one of the male or female wet connect system may be placed in communication with the one of the male or female wet connect system to control the flow control valve and/or to communicate the at least one characteristic of the lateral borehole.
- In other embodiments, the connection system may comprise a wireless communications module configured to wirelessly communicate with a surface location while coupled to an upper portion of the through tubing completion. In some embodiments, the through tubing completion may comprise a wireless communication link configured to wirelessly communicate with a surface location across a gap. In this latter example, the wireless communication link may comprise a coil arrangement to inductively communicate across the gap. Embodiments of the claimed disclosure also may comprise a method for installing a through tubing completion system with the connection system.
- Other or alternative features will become apparent from the following description, from the drawings, and from the claims.
- Certain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying drawings illustrate only the various implementations described herein and are not meant to limit the scope of various technologies described herein. The drawings are as follows:
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FIG. 1 is a schematic illustration of a through tubing completion with a wet mate connector, according to an embodiment of the disclosure; -
FIG. 2 is a schematic illustration of a portion of a through tubing completion with an inductive wet mate connector, according to an embodiment of the disclosure; -
FIG. 3 is a schematic illustration of a portion of a through tubing completion with a retrievable connector, according to an embodiment of the disclosure; -
FIG. 4 is a schematic illustration of a through tubing completion with a hydraulic and electric wet mate connector, according to an embodiment of the disclosure; -
FIG. 5 is a schematic illustration of a through tubing completion with a wireless communication link to the surface, according to an embodiment of the disclosure; -
FIG. 6 is a schematic illustration of a through tubing completion with a short hop wireless communication link to the surface, according to an embodiment of the disclosure; -
FIG. 7 is a schematic illustration of a through tubing completion with a seismic/acoustic wireless communication link to the surface, according to an embodiment of the disclosure; -
FIG. 8 is a schematic illustration of a through tubing completion with a wireless communications link to the surface, according to an embodiment of the disclosure; -
FIG. 9 is a schematic illustration of communication coils employed in the wireless communications link illustrated inFIG. 8 , according to an embodiment of the disclosure; -
FIG. 10 is a schematic illustration of a through tubing completion with a wireless communications link to the surface, according to another embodiment of the disclosure; and -
FIG. 11 is a schematic illustration of communication coils employed in the wireless communications link illustrated inFIG. 10 , according to an embodiment of the disclosure. - In the following description, numerous details are set forth to provide an understanding of some illustrative embodiments of the present invention. However, it will be understood by those skilled in the art that various embodiments of the present invention may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.
- In the specification and appended claims: the terms “connect”, “connection”, “connected”, “in connection with”, and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element”. Further, the terms “couple”, “coupling”, “coupled”, “coupled together”, and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements”. As used herein, the terms “up” and “down”, “upper” and “lower”, “upwardly” and downwardly”, “upstream” and “downstream”; “above” and “below”; and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the invention.
- Embodiments of this disclosure generally relate to a side track or a lateral drilled from an existing completion, referred to as through tubing drilling. Additionally, embodiments also relate to how a side track or lateral bore can be completed without pulling the existing completion and without or with minimal modification of the existing surface infrastructure, referred to as through tubing completion. In some embodiments, the through tubing completion systems relate to intelligent completions or completion systems that are adjustable based on conditions arising in the well.
- Referring in general to
FIGS. 1 and 2 , these drawings show an embodiment of a throughtubing completion system 20 having a communication connection orcoupling system 21 comprising a male coupler wet connect 22 run on acable 24, according to aspects of the present disclosure. As shown, awell system 26 may comprise an existingupper completion 28 including completion components such asproduction tubing 30, e.g. 7 inch production tubing, and a surface controlled subsurface safety valve (SCSSV) 32, e.g. a 7 inch valve, for example. Theproduction tubing 30 and SCSSV 32 may be run in awellbore 34, e.g. a cased wellbore comprising aproduction casing 36, such as a 9⅝ inch production casing. In the example shown, the annulus between theproduction tubing 30 and theproduction casing 36 may be sealed with aproduction packer 38, e.g. a 9⅝ inch production packer. - When the well becomes depleted or begins to water out, a production deflector, or a “whipstock” 40 may be run within the
production tubing 30. The whipstock 40 facilitates a coil tubing or through tubing drilling operation to form a side track orlateral bore 42 to a new productive location. After the lateral bore 42 is formed, the open lateral borehole must be completed to control the flow of production fluid from the borehole. In some embodiments, thelateral borehole 42 may comprise more than oneproductive zone 44, such as in a multi-zone wellbore. For example, threecontrollable zones 44 separated byopen hole packers 46, e.g. swell packers, are shown in this illustration. In some cases at least one passive inflow control device, or “ICD” monitoring gauges may be run in the lateral. - To complete the lateral bore 42, the components of a through bore completion must be able to pass through the smallest diameter of the existing
upper completion 28. In this case, theSCSSV 32 restricts the outer diameter of the through tubing completion to a restricted diameter, e.g. a 5¾ inch diameter. As shown, a throughtubing completion 48 is consequently made up of a smallerdiameter production tubing 50, such as 4 inch diameter production tubing. The smallerdiameter production tubing 50 is sealed to the inner diameter of thelarger production tubing 30 via a portedpacker 52, e.g. a 7 inch ported packer. The portedpacker 52 seals the annulus between the smallerdiameter production tubing 50 and the larger, surroundingproduction tubing 30. Anopening 54 is provided above the portedpacker 52 to allow fluid to flow from the lateral borehole to the surface via the larger production tubing 30 (the opening may be more clearly seen inFIG. 2 ). - Included in the illustrated embodiment of a through
tubing completion 48 are a number of electrically activated flow control valves (FCV) 56. Thevalves 56 may be coupled withsensors 58 to measure and transmit one or more lateral borehole parameters, such as flow rate, pressure, temperature, water cut, resistivity, etc. The information may be coupled to a femalewet connect 60 provided at the top of the throughtubing completion 48. Femalewet connect 60 and malewet connect 22 form connection orcoupling system 21, which in this case is a wet connect system. In addition, acable 62 also may provide communication and/or power to individually control each of the downholeelectric FCVs 56. Coupled to the femalewet connect 60 and thecable 62 is a rechargeable or retrievable battery/power source 64. In this example, thepower source 64 may be configured to only provide power to the variousdownhole sensors 58. Due to the relatively low power draws of thesensors 58, this can help to minimize the size of thepower supply 64. Of course, in other embodiments, thepower source 64 may be employed to electrically operate theFCVs 56. - To download data, recharge the
battery 64, and actuate theFCVs 56, malewet connect 22 may be run in hole on thecable 24. In some cases, the malewet connect 22 may be pulled out of hole (POOH) during production. In other cases, thecable 24 connecting the malewet connect 22 to the surface may be used to provide real time monitoring and control of the lateral bore 42 during periods of production. Additionally, the male and femalewet connect - As illustrated in greater detail in
FIG. 2 , the male and femalewet connect components latching mechanism 66. In this embodiment, thewet connect components inductive coupling 68, although the components are not limited to this example. In other cases, thewet connect components electronics cartridge 70 is coupled intocable 62 beneath theinductive coupling 68; andelectronics 72 are disposed within malewet connect 22. - Turning now to
FIG. 3 , another embodiment of thewet connect components wet connect 22 comprises aretrievable power source 74 conveyed downhole and coupled to the upper end of the throughtubing completion 48. Theretrievable power source 74 may be retrieved at periodic times and allows the throughtubing completion 48 to be configured with smaller or no permanently attached power supplies. In addition to providing power, theretrievable power supply 74 also may have astorage component 76 for recording data obtained by thesensors 58. Once retrieved to the surface, the data may be downloaded and processed for future well system control. - The
retrievable power source 74 also may be used during production. Fluid may flow from the smaller through tubing completion, e.g.completion 48, to the larger existing production tubing, e.g.upper completion 28, as indicated by thearrows 78 in the figure. Power and control of the electronic FCVs 56 (not shown in this figure) may take place autonomously downhole or via wireless signaling. - Referring generally to
FIG. 4 , another embodiment of the throughtubing completion system 20 is illustrated. In this embodiment, the throughtubing completion system 20 comprises a throughtubing completion 48 similar to the through tubing completion described with regards toFIG. 1 . Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail. Instead of the wet connect system primarily communicating electrical power and/or signals, this embodiment has aconnection system 21 comprising a hydraulic and electricalwet connect system 80. Theelectrical components 82 of thewet connect system 80 may communicate electrical power and/or signals via inductive or direct electrical contact. However, in addition to theelectrical components 82, there arehydraulic components 84 of thewet connect system 80. Thehydraulic components 84 couple to the top of the throughtubing completion 48 and provide hydraulic power to theFCVs 56. In this case, hydraulic FCVs are provided in thevarious production zones 44 of thelateral borehole 42. The hydraulic and electricalwet connect system 80 may be hydraulically and electrically coupled to the surface of the well system via ahybrid cable 86 comprising hydraulic andelectric conduits - The
hydraulic component 84 of thewet connect system 80 may be used to provide an adjustment to thehydraulic FCVs 56. The use of hydraulic FCVs eliminates the need for relatively large permanent, retrievable, or rechargeable power supplies. In addition, the open hole packers 46 (if not electrically set or swell packers) may be hydraulically set after running the through tubing completion into the lateral bore. In some cases, a male hydraulicwet connect 92 may be disengaged from a female hydraulicwet connect 94 and pulled out of hole during production of the lateral bore 42. - Referring in general to
FIG. 5 , another embodiment of the throughtubing completion system 20 is illustrated. In this embodiment,system 20 comprises aretrievable communications module 96. Theretrievable communications module 96 may comprise awireless telemetry module 98, a maleinductive coupler 100 ofinductive coupling 68, a downhole power storage/generator module 102, and/or other suitable components. Theretrievable communications module 96 may be sent downhole and coupled to the top of the throughtubing completion 48. - Power and data may be communicated between the
retrievable communications module 96 and the throughtubing completion 48 via the maleinductive coupler 100 and a corresponding femaleinductive coupler 104 of the wetconnect connection system 21. Although male and femaleinductive couplers retrievable communications module 96 and the rest of the throughtubing completion 48, other embodiments may comprise other forms of wet connect (i.e., establishing power/control links downhole) to couple theretrievable communications module 96 and the throughtubing completion 48 together. For example, in some cases the wet connect may include electrical terminals in direct contact with one another. In addition, the maleinductive coupler 100 of theretrievable communications module 96 and the femaleinductive coupler 104 may be engaged together via a latching mechanism, such as latchingmechanism 66. - As described above, the
retrievable communications module 96 may include downhole power generation and/orstorage module 102. The power provided bymodule 102 of theretrievable communications module 96 may be used to power thesensors 58, electricalflow control valves 56, and thewireless communications module 98. The capacity and configuration of thepower module 102 may be determined based on the number of electrical components to energize and on a desired replacement rate. The power storage ofmodule 102 may comprise batteries, capacitors or other forms of power storage. In some embodiments,module 102 comprises power generation capability. - As illustrated in
FIG. 5 , this configuration of theretrievable communications module 96 comprises abore 106 to allow the flow through of production fluid when theretrievable communications module 96 is in place. Accordingly,module 102 may comprise apower generator device 108 such as a turbine to generate power from the fluid flowing through theretrievable communications module 96. At various predetermined intervals or when indicated via a sensor, theretrievable communications module 96 may be retrieved and replaced to provide for future operation of the through tubing completion. - Data obtained by the sensors,
e.g. sensors 58, may be transmitted via thecable 62 to the inductive coupler system 68 (i.e., the male and femaleinductive couplers 100, 104). From theinductive coupler system 68, the data may be sent to thewireless telemetry module 98. Thewireless telemetry module 98 may be configured to transmit data and control signals between the surface and the throughtubing completion 48 via a correspondingwireless telemetry module 110 located at the surface of thewell system 26. This provides for a wireless communications link between the throughtubing completion 48 and an operator located at the surface of the well. - Referring generally to
FIG. 6 , another embodiment of a throughtubing completion system 20 is illustrated. The through tubing completion system illustrated inFIG. 6 may be similar to the through tubing completion system described with respect toFIG. 5 . Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail. - In the embodiment illustrated in
FIG. 6 , the throughtubing completion 48 may be located at a depth in which substantially wireless telemetry is either impractical or inefficient. To compensate for the depth, a series of short hopwireless telemetry modules 112 may be used. The short hopwireless telemetry modules 112 may include one ormore anchors 114 to secure or fix themodules 112 to the existingupper completion 28/production tubing 30. In addition, the short hopwireless telemetry modules 112 may further include a length ofproduction tubing 114, upper and lowerwireless telemetry modules 112, and acable 116 coupling the upper and lower wireless telemetry modules together. Although it is not shown in this figure, the shorthope telemetry modules 112 also may include the power storage/generation module 102 to provide power to the various electrical components associated with the short hopwireless telemetry modules 112. - The short hop
wireless telemetry modules 112 may be retrievable, similar to theretrievable communications module 96 coupled to the throughtubing completion 48. Theshort hop modules 112 may communicate data, power, and other signals between the electricflow control valves 56, thesensors 58, and/or lower wireless telemetry module(s) of an adjacent short hopwireless telemetry module 112. These signals may be communicated to the upperwireless telemetry module 112 viacable 116. The upperwireless telemetry module 112 may then communicate data, power, and other signals to awireless telemetry module 112 located at the surface. Because the transmissions between the correspondingwireless telemetry modules 112 are now over relatively shorter distances, themodules 112 themselves may be made smaller or of lower power than a system wirelessly transmitting to the surface from the throughtubing completion 48. - As shown, in some embodiments, a break between corresponding wireless telemetry modules may occur at a location to allow the
upper completion 28 to retain a previous capability. In the embodiment illustrated inFIG. 6 , for example, there is a short hop wireless transmission across theSCSSV 32, allowing theSCSSV 32 to be able to close when needed. In addition, only one short hop wireless telemetry module is shown above the throughtubing completion 48. However, two or more short hopwireless telemetry modules 112 may be used as needed. In some cases, standardized short hop wireless telemetry modules may replicated as many times as necessary to adequately cover the distance between the throughtubing completion 48 and thewireless telemetry module 112 provided at the surface of thewell system 26. - Referring generally to
FIG. 7 , another illustrative embodiment of the throughtubing completion system 20 is illustrated. The through tubing completion system shown may be similar to the through tubing completion system described with respect toFIG. 5 . Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail. - The retrievable wireless communications modules of
FIGS. 5 and 6 are modified in the exemplary embodiment shown inFIG. 7 . In this latter embodiment, the wireless telemetry module is replaced with adata writer 118, a plurality ofrecorder capsules 120, and awireless signal receiver 122, where thewireless signal receiver 122 is suitable to receive a wireless signal selected from a pressure pulse inside the tubing sent from surface, a low frequency seismic/acoustic signal, an EM signal or a radio frequency type signal. As with the previous retrievable wireless communications modules, a downhole power storage/generator module,e.g. module 102, and a wet connect, such as one of thewet connect systems 21 described above, may be included to power and couple the retrievable wireless communications module to the top of the throughtubing completion 48. - Data from the lateral bore 42 and other systems may be communicated from the
sensors 58 provided in the throughtubing completion 48 and recorded on arecorder capsule 120. A wireless low frequency seismic/acoustic signal may be sent from the surface to the wireless low frequency seismic/acoustic signal receiver 122. Alternately a pressure pulse in the fluid inside the tubing may be sent from surface to thepressure sensor 122. The information carried from the surface by the low frequency seismic/acoustic signal is used to set and control the electronicflow control valves 56 of the throughtubing completion 48. In addition, the wireless low frequency seismic/acoustic signal receiver 122 may instruct arecorder capsule container 124 to release therecorder capsule 120 upon which the data has been written. Therecorder capsule 120 may flow to the surface and provide a surface reader with information regarding the downhole environment and systems. In other embodiments, therecorder capsules 120 may be released at a predetermined time interval or upon another downhole event, such as the detection of water break through by one of the sensors. The recorder capsule system presents a lower cost alternative to the cost and expense of real time systems. - The retrievable wireless communications module may be replaced at predetermined intervals or upon an event, such as parameters indicating the end of life for the
power storage module 102 or exhaustion of the supply ofrecorder capsules 120 from therecorder capsule container 124. During replacement,new recorder capsules 120 may be supplied for an additional time period of monitoring the downhole environment. - Referring in general to
FIG. 8 , another embodiment of the throughtubing completion system 20 is illustrated. In this embodiment,system 20 comprises a wireless communications link 126. Wireless communications link 126 may be employed in awell system 26 having features, configurations, and components, which are the same or similar to many of the components described above with reference to the embodiments illustrated inFIGS. 1-7 . As described above, for example, thewell system 26 may comprise the existingupper completion 28 including completion components such asproduction tubing 30 and surface controlled subsurface safety valve (SCSSV) 32. Theproduction tubing 30 andSCSSV 32 may be run in casedwellbore 34 havingproduction casing 36. In the example shown, the annulus between theproduction tubing 30 and theproduction casing 36 may again be sealed withproduction packer 38. - When the well becomes depleted or begins to water out, the
production deflector 40 may be run within theproduction tubing 30. Theproduction deflector 40 facilitates a coil tubing or through tubing drilling operation to form the side track or lateral bore 42 to a new production location. After the lateral bore 42 is formed, the open lateral borehole is completed to control the flow of production fluid from the borehole. In some embodiments, thelateral borehole 42 may comprise more than oneproduction zone 44, such as in a multi-zone wellbore. - To complete the lateral bore 42, the components of through
bore completion 48 must again be able to pass through the smallest diameter of the existingupper completion 28. For example, theSCSSV 32 may restrict the outer diameter of the throughtubing completion 48. Theproduction tubing 50 of the throughtubing completion 48 is sealed to the inner diameter of the existingproduction tubing 30 via portedpacker 52. The portedpacker 52 effectively seals the annulus between theproduction tubing 50 and thelarger production tubing 30. - Included in this embodiment, the through
tubing completion 48 similarly comprises a number of the electrically activated flow control valves (FCV) 56. The valves may be coupled withsensors 58 configured to measure and transmit one or more lateral borehole parameters, such as flow rate, pressure, temperature, water cut, resistivity, etc. The information may be transferred from (or to) the through tubing completion via thewireless communication link 126 coupled withcable 62. In addition, thecable 62 also may provide communication and/or power to individually control each of the downholeelectric FCVs 56. - At an upper section of the smaller
diameter production tubing 50 of the throughtubing completion 48 illustrated in this embodiment, thewireless communication link 126 is provided to bridge agap 128, such as a gap across theSCSSV 32. In this particular example, thegap 128 across theSCSSV 32 allows the safety valve of the existingupper completion 28 to still properly function in the event of some sort of well system failure. In the illustrated example, thegap 128 is selected to be on the order of 8 to 12 inches wide, which is sufficient to allow the SCSSV flapper to operate. When theSCSSV 32 is closed, communication may be restricted across this gap in some embodiments. - As illustrated, the
wireless communication link 126 has acoil arrangement 130 having acoil 132 positioned generally at an upper section of thetubing 50 of the throughtubing completion 48. A correspondingcoil 134 ofcoil arrangement 130 is positioned across thegap 128. Thecoil arrangement 130 may be across the axis of theproduction tubing 50 or at an angle to theproduction tubing 50, as illustrated in the alternative coil arrangement ofFIG. 9 . In this embodiment, opening 54 is positioned just below thecoil arrangement 130 to allow for the flow of production fluid around the coil arrangement 130 (within the annulus between the smallerdiameter production tubing 50 and the larger production tubing 30). - The corresponding
coil 134 of thecoil arrangement 130 may be provided at the lower end of a section ofproduction tubing 136 that extends to the surface. By way of example,production tubing 136 may have the same diameter asproduction tubing 50. Anopening 138 may be provided through the sidewall ofproduction tubing 136, similar to opening 54, just above the correspondingcoil 134 so that production fluid may flow around the corresponding coil arrangement 130 (from the annulus within thelarger production tubing 30 and back into the interior of the smaller diameter section of production tubing 136). - Both the
coil 132 andcorresponding coil 134 may be coupled by respective cables, such ascables coil 132 and thecorresponding coil 134 each may be formed in a variety of coil arrangements and configurations utilizing individual or multiple coils. Thecoil 132 may be coupled bycable 62 to the electrical components of the throughtubing completion 48 extending into thelateral bore hole 42, such as the electricflow control valves 56 andassorted sensors 58. The correspondingcoil 134 may be coupled bycable 24 to a surface location for monitoring and/or control by an operator. - Referring generally to
FIG. 10 , another embodiment of a throughtubing completion system 20 is illustrated. The throughtubing completion system 20 shown may be similar to the throughtubing completion system 20 described with respect toFIG. 8 . Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail. - In the embodiment of
FIG. 10 , thecoil arrangement 130 of the previous embodiment may be replaced with atoroidal coil arrangement 140. Thetoroidal coil arrangement 140 may be configured to function similar to the previously describedcoil arrangement 130. As shown in the figure, thetoroidal coil arrangement 140 may be provided such that the flapper of anSCSSV 32 can continue to function as intended. Agap 128 of, for example, 8 to 12 inches is provided between correspondingtoroidal coils toroidal coil arrangement 140. In this example, the gap size is selected to allow the flapper to operate while still permitting a reasonable operative level of efficiency and effectiveness in transmitting power and/or communication signals between the toroidal coil arrangements. A cross-sectional view of one of thetoroidal coils FIG. 11 . In this example, thetoroidal coils production tubing 50 and to the lower end ofproduction tubing section 136, respectively. Thecoil arrangement 130 or thetoroidal coil arrangement 140 may be used to relay communication signals and/or power signals across 128. - Elements of the embodiments have been introduced with either the articles “a” or “an.” The articles are intended to mean that there are one or more of the elements. The terms “including” and “having” are intended to be inclusive such that there may be additional elements other than the elements listed. The term “or” when used with a list of at least two elements is intended to mean any element or combination of elements.
- Although only a few embodiments of the present invention have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this invention. Accordingly, such modifications are intended to be included within the scope of this invention as defined in the claims.
Claims (20)
1. A through tubing completion system run in a lateral borehole comprising:
a production tubing coupled to a flow control valve;
one or more sensors measuring at least one characteristic of the lateral borehole;
one of a male or female wet connect system configured to communicatively couple with the flow control valve and the one or more sensors;
wherein a corresponding one of the male or female wet connect system is placed in communication with the one of the male or female wet connect system in order to control the flow control valve and communicate the at least one characteristic of the lateral borehole.
2. The through tubing completion system of claim 1 in which the wet connect system is inductively coupled together.
3. The through tubing completion system of claim 1 in which the wet connect system comprises hydraulic and electrical components.
4. The through tubing completion system of claim 1 in which the flow control valves are electrically actuated.
5. The through tubing completion system of claim 1 in which the flow control valves are hydraulically actuated.
6. The through tubing completion system of claim 1 in which the corresponding one of a male or female wet connect system is included in a retrievable communications module retrievably coupled to an upper portion of the through tubing completion.
7. The through tubing completion system of claim 1 , wherein the wet connect system is inductively coupled together at a location downhole and above the lateral borehole.
8. The through tubing completion system of claim 1 , further comprising a short hop telemetry system to communicate the at least one characteristic of the lateral borehole uphole to a surface location.
9. The through tubing completion system of claim 2 , wherein the wet connect system is inductively coupled together via a coil arrangement.
10. A method for installing a through tubing completion system comprising:
installing a production deflector in an existing completion;
drilling a lateral borehole;
running a through tubing completion comprising a flow control valve and one or more sensors through the existing completion;
coupling communication to a surface via a wet connect system.
11. The method of claim 10 , wherein coupling communication comprises establishing the wet connect system with at least one of hydraulic and electrical components.
12. The method of claim 10 , wherein coupling communication further comprises sending a retrievable communications module downhole to engage an upper portion of the through tubing completion.
13. The method of claim 10 , wherein coupling communication comprises forming an inductive coupling to communicate data uphole from the one or more sensors.
14. The method of claim 13 , wherein forming comprises utilizing a coil arrangement to communicate across a gap.
15. A through tubing completion system run in a lateral borehole comprising:
a production tubing coupled to a flow control valve;
one or more sensors measuring at least one characteristic of the lateral borehole;
a wireless communications module configured to wirelessly communicate with a surface location and coupled to an upper portion of the through tubing completion at a downhole location.
16. The through tubing completion system of claim 15 , wherein the wireless communications module comprises a wireless telemetry module.
17. The through tubing completion system of claim 16 , wherein the wireless telemetry module communicates with the surface location via one or more short hop wireless telemetry modules.
18. The through tubing completion system of claim 15 , wherein the wireless communications module comprises a data writer, and a recordable capsule container releasably containing a plurality of recordable capsules;
wherein sensor data is recorded on one of the plurality of recordable capsules which is released to the surface.
19. The through tubing completion system of claim 15 , wherein the wireless communications module comprises a coil arrangement to inductively communicate across a gap.
20. The through tubing completion system of claim 19 , wherein the coil arrangement comprises a toroidal coil arrangement for communicating at least one of communication or power signals across the gap.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/021,744 US20110192596A1 (en) | 2010-02-07 | 2011-02-05 | Through tubing intelligent completion system and method with connection |
NO20110206A NO20110206A1 (en) | 2010-02-07 | 2011-02-07 | System and method for intelligent completion through production rudder, with coupling. |
Applications Claiming Priority (4)
Application Number | Priority Date | Filing Date | Title |
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US30213810P | 2010-02-07 | 2010-02-07 | |
US30213710P | 2010-02-07 | 2010-02-07 | |
US30223210P | 2010-02-08 | 2010-02-08 | |
US13/021,744 US20110192596A1 (en) | 2010-02-07 | 2011-02-05 | Through tubing intelligent completion system and method with connection |
Publications (1)
Publication Number | Publication Date |
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US20110192596A1 true US20110192596A1 (en) | 2011-08-11 |
Family
ID=44352765
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/021,744 Abandoned US20110192596A1 (en) | 2010-02-07 | 2011-02-05 | Through tubing intelligent completion system and method with connection |
Country Status (2)
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US (1) | US20110192596A1 (en) |
NO (1) | NO20110206A1 (en) |
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