I lllll llllllll Ill lllll lllll lllll lllll lllll 111111111111111111111111111111111
`US008451137B2
`
`c12) United States Patent
`Bonavides et al.
`
`(10) Patent No.:
`(45) Date of Patent:
`
`US 8,451,137 B2
`May 28, 2013
`
`(54) ACTUATING DOWNHOLE DEVICES IN A
`WELLBORE
`
`(75)
`
`Inventors: Clovis S. Bonavides, Houston, TX (US);
`Donald L. Crawford, Spring, TX (US)
`
`(73) Assignee: Halliburton Energy Services, Inc.,
`Houston, TX (US)
`
`( *) Notice:
`
`Subject to any disclaimer, the term ofthis
`patent is extended or adjusted under 35
`U.S.C. 154(b) by 1185 days.
`
`(21) Appl. No.: 12/244,316
`
`(22)
`
`Filed:
`
`Oct. 2, 2008
`
`(65)
`
`Prior Publication Data
`
`US 2010/0085210Al
`
`Apr. 8, 2010
`
`(51)
`
`Int. Cl.
`GOJV3/00
`(52) U.S. Cl.
`USPC .................. 340/855.7; 340/853.3; 340/855.4;
`166/250.01
`
`(2006.01)
`
`( 58) Field of Classification Search
`USPC ............. 340/853.3, 855.4, 855.7; 166/250.01
`See application file for complete search history.
`
`(56)
`
`References Cited
`
`U.S. PATENT DOCUMENTS
`102/200
`4,884,506 A * 12/1989 Guerreri
`5,166,677 A * 1111992 Schoenberg ............... 340/853.3
`6,478,090 B2 * 1112002 Deaton
`166/363
`
`166/297
`175/4.55
`.................... 367/81
`166/373
`166/250.01
`166/250.17
`166/297
`
`6,604,584 B2
`8/2003 Lerche et al.
`7,980,309 B2 * 7/2011 Crawford.
`8,074,737 B2 * 12/2011 Hill eta!.
`200110043509 Al* 1112001 Green et al.
`2003/0000706 Al *
`112003 Carstensen
`2003/0015319 Al*
`112003 Green et al.
`2005/0022987 Al*
`212005 Green et al.
`2005/0045331 Al* 3/2005 Lerche et al.
`2005/0046592 Al
`3/2005 Cooper et al.
`2006/0039238 Al
`212006 Mandal et al.
`2007/0019506 Al
`1/2007 Mandal et al.
`2007 /0096941 Al * 5/2007 Morys ........................ 340/853.l
`7/2007 Bonavides et al.
`2007/0152054 Al
`2009/0272529 Al
`1112009 Crawford
`2010/0005992 Al
`1/2010 Crawford
`* cited by examiner
`
`Primary Examiner -
`Jennifer H Gay
`Assistant Examiner - Catherine Loikith
`(74) Attorney, Agent, or Firm - Paul I. Herman; Fish &
`Richardson P.C.
`
`(57)
`
`ABSTRACT
`A downhole tool system includes a first downhole tool and a
`second downhole tool. The first downhole tool includes a first
`controller operable to receive an actuation signal including a
`tone. The first controller actuates the first downhole tool ifthe
`tone is a first specified frequency and changes the first down(cid:173)
`hole tool to communicate the actuation signal to the second
`downhole tool if first downhole tool is not actuated in
`response to the actuation signal. A second downhole tool
`includes a second controller operable to receive the actuation
`signal. The second controller actuates the second downhole
`tool if the tone is a second specified frequency. The second
`frequency is different from the first frequency.
`
`33 Claims, 6 Drawing Sheets
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 001
`
`

`

`U.S. Patent
`
`May 28, 2013
`
`Sheet 1of6
`
`US 8,451,137 B2
`
`..
`
`:
`
`.
`
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`,
`
`.... ··../·······
`
`FIG. 1
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 002
`
`

`

`U.S. Patent
`
`May 28, 2013
`
`Sheet 2 of 6
`
`US 8,451,137 B2
`
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`FIG, 2
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 003
`
`

`

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`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 004
`
`

`

`U.S. Patent
`
`May 28, 2013
`
`Sheet 4 of 6
`
`US 8,451,137 B2
`
`.,.......,.. __ ...._: ............
`
`r-.....
`.......
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`!
`
`0 c
`
`("()
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 005
`
`

`

`U.S. Patent
`
`May 28, 2013
`
`Sheet 5 of 6
`
`US 8,451,137 B2
`
`l..r410
`f Surface
`I
`l
`
`415C
`
`400~
`
`405"'\
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`415d
`
`420-.,
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`
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`425b
`
`i Bottom of VVeBbore
`
`440/
`
`FIG. 5
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 006
`
`

`

`U.S. Patent
`
`May 28, 2013
`
`Sheet 6 of 6
`
`US 8,451,137 B2
`
`Surface ControBer
`Receives Command
`to Actuate
`Down hole 1 oo!
`
`Surface Controller
`Puts Power and
`Unique, Timed Serial
`Signal Over
`Transmission Path
`
`606·-.....
`i
`l
`..,
`,
`Dovmho!e Tool
`Controller
`Receives Signal
`608~"
`~
`.............. t ................ A ............................ _
`Too! ControHer in
`Wake Mode
`
`.. _ ..
`
`Too! Controller Runs
`Automatic Signal
`Detection Routine
`
`Tool Control!er
`Cumpares Timed
`Serial Signal to
`Stored Slgna!
`
`Po»Ner and S!gnal
`Removed from
`Transmission Path
`
`f ' f
`' l
`
`....................... i ................... :. .... _ ....................... .
`
`i
`620--,
`Short Circuit
`Condition Occurs on
`Transmission Path
`
`626-
`
`Timed Serial
`Signal Transmitted
`to Next Downho!e
`Tool Controller
`
`Downho!e
`Too! Actuates
`
`r.
`:
`624·-...\
`616-~,
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`Tool Controller
`Too! Controller
`Closes Pov1er(cid:173)
`Closes Actuation
`Svvitch
`Contro! Switch
`
`FIG, 6
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 007
`
`

`

`US 8,451,137 B2
`
`1
`ACTUATING DOWNHOLE DEVICES IN A
`WELLBORE
`
`BACKGROUND
`
`This disclosure relates to actuating downhole devices in a
`wellbore and, more particularly, actuating downhole devices
`over a wireline by a tonal signal.
`Downhole tools and devices utilized in a wellbore may
`accomplish a number of different tasks. For example, some
`downhole tools are used for perforating the well bore to allow
`fluids from the geological formation to enter the wellbore and
`eventually be produced. Downhole tools may also be utilized
`to measure various characteristics of the geological formation
`surrounding the wellbore; introduce cement, sand, acids, or 15
`other chemicals to the wellbore; and perform other opera(cid:173)
`tions.
`In certain instances, downhole tools, such as explosive
`perforating tools, or "guns," utilize a combination of chang(cid:173)
`ing voltage polarity and pressure actuated switches in order to
`activate. For example, a downhole tool may consist of a string
`of guns physically and electrically connected by a wireline in
`the wellbore and positioned vertically in the wellbore at a
`particular depth. In order to activate the first gun in the string,
`i.e., the deepest gun in the string, a positive voltage signal may
`be transmitted via the wireline to the first gun, actuating the
`gun and causing the explosive charge to detonate. A pressure(cid:173)
`actuated mechanical switching switch may then shift to allow
`negative polarity only through the wireline. The second gun
`in the string, i.e., the next deepest gun in the string, may only
`be actuated with negative polarity. Once the second gun is
`actuated by transmitting negative polarity through the wire(cid:173)
`line, the pressure-actuated mechanical switching switch may
`shift to allow only positive polarity voltage through the wire(cid:173)
`line. The third gun in the string may only be actuated with
`positive voltage. The foregoing sequence of positive and
`negative voltage actuated tools may be repeated for any num(cid:173)
`ber of tools. The pressure actuated mechanical switching
`switch, however, may be shifted accidentally due to forma(cid:173)
`tion characteristics. Moreover, guns actuated by switching
`polarity may be prone to accidental actuation.
`
`SUMMARY
`
`In certain aspects, a downhole tool system includes a first 45
`downhole tool and a second downhole tool. The first down-
`hole tool includes a first controller operable to receive an
`actuation signal including a tone. The first controller actuates
`the first downhole tool if the tone is a first specified frequency
`and changes the first downhole tool to communicate the
`actuation signal to the second downhole tool if first downhole
`tool is not actuated in response to the actuation signal. A
`second downhole tool includes a second controller operable
`to receive the actuation signal. The second controller actuates
`the second downhole tool if the tone is a second specified 55
`frequency. The second frequency is different from the first
`frequency.
`Certain aspects encompass a method for actuating a down(cid:173)
`hole tool in a well bore. In the method, power for tool actua(cid:173)
`tion and a first actuation signal including a first tone is 60
`received at a first downhole tool. A frequency of the first tone
`in the first actuation signal is compared to a first reference
`frequency. The first downhole tool is actuated in response to
`the comparison of the first actuation signal and the first ref(cid:173)
`erence frequency. Power for tool actuation and a second 65
`actuation signal including a second tone is received at a sec(cid:173)
`ond downhole tool. The frequency of the second tone in the
`
`2
`second actuation signal is compared to a second reference
`frequency. The second downhole tool is actuated in response
`to the comparison of the second actuation signal and the
`second reference frequency.
`Certain aspects encompass a method for actuating a down(cid:173)
`hole tool in a well bore. In the method, a tonal signal and
`power for actuating the downhole tool is received at the
`downhole tool. It is determined whether the tonal signal cor(cid:173)
`responds to the downhole tool by comparing a frequency of
`10 the tonal signal to a reference frequency associated with the
`downhole tool. Based upon the determination of whether the
`tonal signal corresponds to the downhole tool, the downhole
`tool is changed to apply the power to actuate the downhole
`tool.
`Additionally, all or some or none of the described imple-
`mentations may have one or more of the following features or
`advantages. For example, downhole tools may be actuated by
`a surface command over a mono-conductor wireline path.
`Also, downhole tools may be actuated singularly using tonal
`20 signals that serve both as the signal to actuate and to address
`a specific tool. As another example, downhole tools may be
`actuated by such a tonal signal involving a pattern of frequen(cid:173)
`cies. In certain instances, a different specified or reference
`frequency can be uniquely associated with a given downhole
`25 device, controller and/or tool of the string in the wellbore. As
`a further example, downhole tools actuated by tonal signals
`may be less prone to accidental actuation due to random
`signals or random events. Also, downhole tools actuated by
`tonal signals may be less sensitive to signal level fluctuations
`30 and generally less prone to signal decoding errors. As yet
`another example, downhole tools may not be accidentally
`actuated because the power can be transmitted only to the
`tools being actuated. Further, the downhole tools may include
`additional safety features such as actuation switches. As
`35 another example, a system including downhole tools may be
`more cost efficient by avoiding various mechanical and elec(cid:173)
`trical complexities inherent with certain digital controls. As a
`further example, various components within the described
`implementations may be more size-efficient and more easily
`40 integrate with existing downhole tool technology. Addition(cid:173)
`ally, downhole tools may be actuated without the use of
`communications protocols and a multi-wire bus. Also, a sys(cid:173)
`tem for actuating downhole tools may, in part, utilize metallic
`housings of downhole tools as a ground reference of the
`system.
`These general and specific aspects may be implemented
`using a device, system or method, or any combinations of
`devices, systems, or methods. The details of one or more
`implementations are set forth in the accompanying drawings
`50 and the description below. Other features, objects, and advan(cid:173)
`tages will be apparent from the description and drawings, and
`from the claims.
`
`DESCRIPTION OF DRAWINGS
`
`FIG. 1 illustrates one example of a well system which may
`utilize a downhole device in accordance with the concepts
`described herein;
`FIG. 2 is a block diagram illustrating a general implemen(cid:173)
`tation of a downhole device in accordance with the concepts
`described herein;
`FIG. 3 is a circuit diagram illustrating an example of a
`downhole device in accordance with the concepts described
`herein;
`FIG. 4 is a block diagram illustrating an example device for
`actuating a downhole tool from the surface in accordance
`with the concepts described herein;
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 008
`
`

`

`US 8,451,137 B2
`
`3
`FIG. 5 is a block diagram illustrating an example system
`for actuating a downhole tool in accordance with the concepts
`described herein; and
`FIG. 6 is a flowchart illustrating an example method for
`actuating a downhole tool in accordance with the concepts
`described herein.
`
`DETAILED DESCRIPTION
`
`This disclosure provides various implementations for actu(cid:173)
`ating downhole devices and, more particularly, for actuating
`downhole devices by tonal signals over a transmission path.
`For example, a downhole device may include a downhole tool
`controller coupled to a downhole tool. Upon receipt of a tonal
`signal from a system controller at the surface or at another
`location (e.g., in the well bore) via the transmission path, the
`downhole tool controller compares the tonal signal to a speci(cid:173)
`fied signal associated with the downhole device to determine
`a match or other correspondence. In some instances, multiple
`downhole devices may be provided on the transmission path,
`and each downhole device may be associated with a different
`specified signal. The tonal signal may be a signal with a
`specified frequency and/or duration or a pattern of frequen(cid:173)
`cies and/or durations. If no match or correspondence of the
`tonal signal is determined, the downhole device performs in a
`first manner. Upon a match or correspondence of the tonal
`signal, the downhole device may perform in a second, differ(cid:173)
`ent manner. For example, in one implementation, if no match
`of the tonal signal is determined, the downhole tool of the
`downhole device can remain unchanged (e.g. not actuate). If
`a match between the signals is determined, the downhole tool
`of the downhole device can actuate. In some implementa(cid:173)
`tions, the downhole tool of the downhole device may receive
`power from the surface and transmit the power and the signal
`to the next downhole device if no match of the tonal signal is 35
`determined. Of note, performing in the first or the second
`manner can include not responding to the tonal signal what(cid:173)
`soever.
`FIG. 1 illustrates one example of a well system 10 which
`may utilize one or more implementations of a downhole
`device in accordance with the present disclosure. Well system
`10 includes a drillingrig 12, a wireline truck 14, a wireline 16
`(e.g., slickline, braided line, or electric line), a subterranean
`formation 18, a wellbore 20, and a downhole tool set 22.
`Drilling rig 12, generally, provides a structural support sys(cid:173)
`tem and drilling equipment to create vertical or directional
`wellbores in sub-surface zones. As illustrated in FIG. 1, drill(cid:173)
`ing rig 12 may create wellbore 20 in subterranean formation
`18. Wellbore 20 may be a cased or open-hole completion
`borehole. Subterranean formation 18 is typically a petroleum
`bearing formation, such as, for instance, sandstone, Austin
`chalk, or coal, as just a few of many examples. Once the
`wellbore 20 is formed, wireline truck 14 may be utilized to
`insert the wireline 16 into the wellbore 20. The wireline 16
`may be utilized to lower and suspend one or more of a variety 55
`of different downhole tools in the wellbore 20 for wellbore
`maintenance, logging, completion, workover, and other
`operations. In some instances, a tubing string may be alter(cid:173)
`natively, or additionally, utilized in lowering and suspending
`the downhole tools in the wellbore 20.
`The downhole tools can include one or more of perforating
`tools (perforating guns), setting tools, sensor initiation tools,
`hydro-electrical device tools, pipe recovery tools, and/or
`other tools. Some examples of perforating tools include
`single guns, dual fire guns, multiple selections of selectable
`fire guns, and/or other perforating tools. Some examples of
`setting tools include electrical and/or hydraulics setting tools
`
`4
`for setting plugs, packers, whip stock plugs, retrieve plugs, or
`perform other operations. Some examples of sensor initiation
`tools include tools for actuating memory pressure gauges,
`memory production logging tools, memory temperature
`tools, memory accelerometers, free point tools, logging sen(cid:173)
`sors and other tools. Some examples of hydro-electrical
`device tools include devices to shift sleeves, set packers, set
`plugs, open ports, open laterals, set whipstocks, open whip(cid:173)
`stock plugs, pull plugs, dump beads, dump sand, dump
`10 cement, dump spacers, dump flushes, dump acids, dump
`chemicals or other actions. Some examples of pipe recovery
`tools include chemical cutters, radial torches, jet cutters, junk
`shots, string shots, tubing punchers, casing punchers, electro(cid:173)
`mechanical actuators, electrical tubing punchers, electrical
`15 casing punchers and other pipe recover tools.
`In the present example, tool set 22 may include one or more
`downhole devices 24. The downhole devices 24 may be
`coupled together with a threaded connector 26. In some
`implementations, the wireline 16 is the transmission path and
`20 downhole devices 24 may be actuated by one or more signals
`over the wireline 16 according to the concepts described
`herein. In certain implementations, the transmission path can
`take additional or alternative forms (e.g., electrical, fiberoptic
`or other type of communication line carried apart from the
`25 wireline 16, electrical, fiber optic or other type of communi(cid:173)
`cation line carried in or on tubing, or other transmission
`paths).
`FIG. 2 is a block diagram illustrating one example of a
`downhole device 100 operable for placement within a well-
`30 bore used, for instance, as an oil well or gas well. Generally,
`downhole device 100 includes a downhole tool 145 and a tool
`controller 105, where the tool controller 105 is coupled to a
`transmission path 110. The tool controller 105 receives a
`actuation signal comprising a tone (referred to herein as a
`"tonal signal") via the transmission path 110 and compares
`the tonal signal to a specified reference signal (e.g. a specified
`reference tone or tones and/ or a specified reference duration)
`associated with the downhole device. If the tonal signal
`received via the transmission path 110 matches or otherwise
`40 corresponds to the specified reference signal, the tool control(cid:173)
`ler 105 acts (or refrains from acting) to cause the downhole
`tool 145 to perform in a first manner. If the signals do not
`match or correspond, the tool controller 105 acts (or refrains
`from acting) to cause the downhole tool 145 to perform in a
`45 second, different manner. In some instances, as is described in
`more detail below, the first manner of performance can be
`actuating the downhole tool and the second manner of per(cid:173)
`formance can be not actuating the downhole tool. The tool
`controller 105 can determine signals do not match and relay
`50 the signal to another downhole device 100.
`The tonal signal can be a single tone of a given frequency
`or may have multiple tones of the same and/or different fre(cid:173)
`quencies. In tonal signals having multiple tones, each tone
`may have the same and/or different time durations. Different
`combinations of the number of tones, the frequency of the
`tones and the duration of the tones may be used to address
`different of the downhole devices. In an example using a
`single tone to address and actuate a specific downhole device,
`the specified reference signal associated with the specific
`60 downhole device can be a single specified reference fre(cid:173)
`quency. If duration is taken into account, the specified refer(cid:173)
`ence signal can also include a specified time duration or a
`minimum specified time duration. For example, the downhole
`device can be configured to perform in the first manner only
`65 after receiving a tonal signal that matches in frequency and
`duration to its specified reference signal. The specified refer(cid:173)
`ence signal (frequencies and/or duration) can be unique from
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 009
`
`

`

`US 8,451,137 B2
`
`5
`other specified reference signals associated with other down(cid:173)
`hole devices on the same transmission path. Unlike a binary
`tonal system, the system described herein can utilize three or
`more and/or five or more different frequencies. In certain
`instances, there can be at least one unique specified reference
`signal per downhole device on the transmission path (e.g.,
`five downhole devices can utilize five different specified ref(cid:173)
`erence signals). In certain instances, groups of two or more
`downhole devices on a transmission path can be responsive in
`the first manner to the same tonal signal. In certain instances,
`one or more of the downhole tools on a transmission path are
`responsive in the first manner only to a specified frequency or
`a plurality of specified frequencies each played for specified
`durations.
`The frequencies may be of any value and for any time
`duration (e.g., seconds, milliseconds, etc.). In certain
`instances, the duration of a tone is 0.5 s or greater. In certain
`instances, the frequencies can correspond to the frequencies
`used in telephone networks (2, 3, 4, 5, 6, 7, 8, 9, 10, 11 and 12
`kHz). Although referred to as "tonal," the tonal signals need
`not be audible or within the frequency range of sounds
`audible to a human.
`In this example, the downhole device 100 the transmission
`path 110 transmits both power to power and actuate the down(cid:173)
`hole tool 145 and the tonal signal. In some instances, the
`transmission path 110 may omit power or may provide power
`enough to operate the tool controller 105 but not enough to
`actuate the tool 145. In some aspects, the downhole device
`100 may consist of a downhole tool 145 integrally coupled to
`a tool controller 105 such that, for example, at least portions
`of the downhole tool 145 and tool controller 105 are enclosed
`within a common housing. In certain instances, the downhole
`tool 145 and tool controller 105 can be provided partially or
`wholly in two or more separate housings.
`The example tool controller 105 includes a power module
`115, a processor module 125, a crystal oscillator 130, an
`actuation switch 135, and a power-control switch (PCS) 140.
`The tool controller 105 may also include a signal conditioner
`120. The power module 115 consists of a resistor 116 in series 40
`with a Zener diode 117 and receives power via the transmis(cid:173)
`sion path 110 to supply power to the tool controller 105 and its
`components. Signal conditioner 120 may be coupled from the
`transmission path 110 to the processor module 125 and gen(cid:173)
`erally acts as an analog filter for signals transmitted to the tool
`controller 105 via the transmission path 110. For example, the
`tool controller 105 may actuate the downhole tool 145 upon
`receipt of a tonal signal. The signal conditioner 120, when
`implemented, may filter undesirable frequency variations
`from the tonal signal and provide a cleaner frequency signal 50
`to the processor module 125. In some implementations, the
`signal conditioner 120 may consist of one or more capacitors.
`Processor module 125 is coupled to the power module 115,
`crystal oscillator 130, actuation switch 135, and PCS 140.
`The processor module 125 may also be coupled to the signal 55
`conditioner 120. Generally, the processor module 125 con(cid:173)
`trols the actuation switch 135 and PCS 140 based on the tonal
`signal received through transmission path 110 by executing
`instructions and manipulating data to perform the operations
`of the tool controller 105. Processor module 125 may be, for
`example, a central processing unit (CPU), an application
`specific integrated circuit (ASIC), a field-programmable gate
`array (FPGA) and/or other type of processor. Although FIG.
`2 illustrates a single processor module 125 in tool controller
`105, multiple processor modules 125 may be used according
`to particular needs and reference to processor module 125 is
`meant to include multiple processors 125 where applicable.
`
`6
`The processor module 125 includes or is communicably
`coupled to a signal decoder 126, memory 127, and a control
`circuit 128. As shown in FIG. 2, the signal decoder 126,
`memory 127, and control circuit 128 may be integral to the
`processor module 125. In some aspects, however, the decoder
`126, memory 127, and control circuit 128 may be physically
`separated yet communicably coupled to each other, as well as,
`the processor module 125. The signal decoder 126 includes
`logic and software and, generally, receives the tonal signal via
`10 the transmission path 110 and decodes the signal for com(cid:173)
`parison to a stored signal in the memory 127. Regardless of
`the particular implementation, "software" may include soft(cid:173)
`ware, firmware, wired or programmed hardware, or any com(cid:173)
`bination thereof.
`15 Memory 127 may include any memory or database module
`and may take the form of volatile or non-volatile memory
`including, without limitation, flash memory, magnetic media,
`optical media, random access memory (RAM), read-only
`memory (ROM), removable media, or any other local or
`20 remote memory component. Furthermore, although illus(cid:173)
`trated in FIG. 2 as a single memory 127, multiple memory
`modules 127 may be utilized in the tool controller 105.
`Memory 127, generally, stores instructions and routines
`executed by the processor module 125 to, for example,
`25 decode the tonal signal transmitted to the tool controller 105,
`compare the tonal signal to the stored reference signal resid(cid:173)
`ing in memory 127, and control the operation of the actuation
`switch 135 and PCS 140. In short, the memory 127 may store
`data and software executed by the processor module 125 to
`30 operate and control the tool controller 105.
`Control circuit 128 includes analog and/or digital circuitry
`operable to control the actuation switch 135 and PCS 140
`based on the tonal signal received via the transmission path
`110 and the operation of the processor module 125. Gener-
`35 ally, the control circuit 128 operates to close the actuation
`switch 135 based on a match of the tonal signal transmitted to
`the tool controller 105 and the stored signal in memory 127.
`The control circuit 128 also operates to close the PCS 140 if
`the tonal signal does not match the stored signal.
`Continuing with FIG. 2, the tool controller 105 may also
`include crystal oscillator 130 coupled to the processor mod(cid:173)
`ule 125. In some embodiments, the tonal signal may be a
`frequency signal transmitted to the tool controller 105. The
`crystal oscillator 130, such as a piezoelectric crystal resona-
`45 tor, can provide a reliable frequency reference that may be
`utilized by the signal decoder 126 to perform reliable fre(cid:173)
`quency measurements. In some instances, two or more crystal
`oscillators 130 can be included in the tool controller 105.
`Actuation switch 135 is coupled to the transmission path
`110, the processor module 125, and a downhole tool 145.
`When closed, the actuation switch 135 provides power from
`the transmission path 110 to the downhole tool 145, thus
`activating the downhole tool 145. In some instances, the
`downhole tool 145 may be a perforating tool including a
`detonating explosive charge. In such instances, the actuation
`switch 135 may be rated at 180 volts and 0.001 amps to
`accommodate a high-voltage, low-current detonator. The
`actuation switch 135 may also be rated to accommodate a
`low-voltage, high-current detonator, such as a switch 135
`60 rated at 42 volts and 0.8 amps. Actuation switch 135, how(cid:173)
`ever, may be sized to accommodate both high-voltage and
`high-current thereby allowing it to function with either type
`of detonator.
`PCS 140 is coupled to the transmission path 110 and the
`65 processor module 125, and generally, operates to interrupt or
`allow power to be transmitted on the transmission path 110
`past the tool controller 105. For example, in some instances,
`
`Hunting Titan, Inc.
`Ex. 1017
`Pg. 010
`
`

`

`US 8,451,137 B2
`
`7
`multiple tool controllers 105 may be coupled to the transmis(cid:173)
`sion path 110. If the processor module 125 operates the PCS
`140 to open on a particular tool controller 105, power is
`interrupted to additional tool controllers located downstream
`on the transmission path 10.
`Downhole tool 145 is coupled to the tool controller 105
`through the actuation switch 135. Generally, the downhole
`tool 145 may be any tool or device capable of performing a
`particular function or action in a wellbore. For example, the
`downhole tool 145 may be an explosive setting tool, an elec- 10
`trical setting tool, a sensor initiating memory tool, a hydro(cid:173)
`electrical tool, or a fire pipe recovery tool. As an explosive
`setting tool or electrical setting tool, the downhole tool 145
`may: set plugs, set packers, set whipstock plugs, or retrieve
`plugs. As a sensor initiating memory tool, the downhole tool 15
`145 may be a memory pressure gauge, a memory high-speed
`pressure gauge, a memory production logging tool, a memory
`temperature tool, a memory accelerometer, a free point tool,
`or a logging sensor. As a hydro-electrical tool, the downhole
`tool 145 may: shift sleeves, set a packer, set plugs, open ports, 20
`open laterals, set whipstocks, open whipstock plugs, pull
`plugs, dump beads, dump sand, dump cement, dump spacers,
`dump flushes, dump acids, or dump chemicals.
`In one implementation, the downhole tool 145 may be a
`perforating tool system including, for example, a single per- 25
`forating tool, two or more perforating tools, a tubular string of
`selectable perforating tools, or a dual fire tool. In the present
`example, the perforating tool includes an explosive detonator
`that may be enclosed within a common housing with the tool
`controller 105. Thus, when the actuation switch 135 is closed 30
`by the processor module 125, power is supplied to the perfo(cid:173)
`rating tool, actuating the explosive detonator. The resultant
`explosion may destroy some or all of the perforating tool
`itself along with the tool controller 105, thereby creating a
`short-circuit (i.e., over-current) condition on the transmission 35
`path 110.
`FIG. 3 is a circuit diagram illustrating one specific example
`of a downhole device 200. FIG. 3 illustrates one specific
`example of a downhole device 200, including resistors, tran(cid:173)
`sistors, diodes, capacitors, processor, and switches, other 40
`combinations of analog and/or digital circuitry and hardware
`may also be utilized without departing from the scope of the
`current disclosure. Generally, downhole device 200, includ(cid:173)
`ing tool controller 205 and downhole tool 245 may operate
`similarly to the downhole device 100, including tool control- 45
`!er 105 and downhole tool 145, illustrated in FIG. 2. In some
`aspects, downhole device 200 may also include a diagnostic
`module 250, which allows the device 200 to be tested.
`Tool controller 205 is coupled to a transmission path 210
`and downhole tool 245. Tool controller 205 includes a power 50
`module 215, a processor module 22