EP3563033B1 - Bohrlochkommunikation - Google Patents

Bohrlochkommunikation Download PDF

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Publication number
EP3563033B1
EP3563033B1 EP16829111.0A EP16829111A EP3563033B1 EP 3563033 B1 EP3563033 B1 EP 3563033B1 EP 16829111 A EP16829111 A EP 16829111A EP 3563033 B1 EP3563033 B1 EP 3563033B1
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EP
European Patent Office
Prior art keywords
downhole
well
harvesting
module
data communication
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Active
Application number
EP16829111.0A
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English (en)
French (fr)
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EP3563033A1 (de
Inventor
Leslie David Jarvis
Shaun Compton Ross
Steven Martin Hudson
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Metrol Technology Ltd
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Metrol Technology Ltd
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Publication of EP3563033A1 publication Critical patent/EP3563033A1/de
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    • 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
    • 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
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/066—Valve arrangements for boreholes or wells in wells electrically actuated
    • 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
    • E21B41/0085—Adaptations of electric power generating means for use in boreholes
    • 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
    • E21B41/02—Equipment or details not covered by groups E21B15/00 - E21B40/00 in situ inhibition of corrosion in boreholes or wells
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure

Definitions

  • This invention relates to downhole communication and energy harvesting. It relates to methods and systems for powering a downhole device in a well installation having metallic structure provided with cathodic protection.
  • US6469635B1 describes a data transmission system for use in extracting data from a downhole location in a well.
  • the well has electrically conductive downhole structure which together with an earth return forms a signal circuit which is used to transmit data.
  • a current source is provided at the wellhead for applying a reference signal to the downhole structure.
  • Effective impedance varying means are located downhole and used for varying the effective impedance of the signal circuit in dependence on data to be transmitted to the wellhead.
  • US2014218208A1 describes a system for delivery of power downhole.
  • US2014320301 A1 describes a lateral bore communication system where data signals are transmitted across the break in conductive path between a main bore and a lateral bore using a downhole structure section which has an electrode provided around a tubing portion and separated therefrom by an insulating layer.
  • US2009078585A1 describes a method comprising providing one or more electrical appliances which each have a pair of electrical contacts; connecting one electrical contact of each electrical appliance to the structure, and connecting the other electrical contact of each electrical appliance to earth, thereby providing electrical power to each of the electrical appliances.
  • US2013293029A1 describes an electrical power and/or electrical signal transmission system for transmitting electrical power and/or electrical signals from a location on a first side of a metallic wall to a location on a second side of the metallic wall and includes a transmitting apparatus having an electrical source and a first transformer.
  • the expression surface encompasses the land surface in a land well where a well head will be located, the seabed/mudline in a subsea well, and a well head deck on a platform. It also encompasses locations above these locations where appropriate.
  • surface is used to refer to any convenient location for applying and/or picking up power/signals for example, which is outside of the borehole of the well.
  • the modulation means may be arranged to at least one of:
  • the second communication module may be arranged for location downhole.
  • the apparatus may comprise a sensor module for sensing at least one parameter, wherein the first communication module is arranged for sending data encoding readings from the sensor module towards the second communication module.
  • the sensor module may comprise a pressure sensor.
  • the second communication module may be arranged for providing data to a downhole device in dependence on data received by the second communication module from the first communication module.
  • the downhole device may comprise at least one of:
  • the valve may comprise at least one of:
  • At least one of the first and second communication modules may comprise a communications repeater for location downhole in a well and arranged for communicating with a first device beyond the well head using a communication channel which is wireless at least through the well head and arranged for communicating with second device located in the well and thus below the well head such that the communications repeater may act as a repeater between the first and second devices.
  • the harvesting module may be arranged to harvest electrical energy from dc currents.
  • a downhole data communication system comprising downhole data communication apparatus as defined above located in a well installation having metallic structure provided with cathodic protection.
  • the apparatus may comprise a downhole electrical power harvesting module electrically connected between two spaced locations in the well installation and comprising an electrical circuit arranged for harvesting electrical energy, in use, from a potential difference between the spaced locations, used for harvesting, which acts as an input voltage, the harvesting module being arranged for supplying power to at least one component of the communication apparatus.
  • the current flow within portions of the metallic structure in regions between the spaced locations, used for harvesting, may be in the same longitudinal direction.
  • At least one of the first communication module and the second communication module may be located in an enclosed annulus of the well.
  • the system or apparatus may comprise a pressure sensor arranged for monitoring the reservoir pressure of the well.
  • the system or apparatus may comprise a pressure sensor arranged for monitoring the pressure in an annulus of the well.
  • the system or apparatus may comprise a pressure sensor arranged for monitoring the pressure in an enclosed annulus of the well.
  • the harvesting module may comprise control means for modifying the input impedance of the electrical circuit to match the source impedance of the electrical circuit to optimise power conversion efficiency.
  • the electrical circuit may comprise a dc-dc convertor.
  • the dc-dc convertor may be arranged to operate with input voltages above a minimum threshold, wherein the minimum threshold is not greater than 0.5 volt, preferably the minimum threshold is not greater than 0.25 volts, and more preferably the minimum threshold is not greater than 0.05 volts.
  • the dc-dc converter may comprise self-start means to allow initiation of energy harvesting when the available input voltage is below a semiconductor band gap voltage of components in the dc-dc convertor.
  • the dc-dc converter may comprise self-start means to allow initiation of energy harvesting when the available input voltage is below 0.5 volts.
  • the dc to dc converter may comprise a step-up transformer.
  • the self-start means may comprise a Field Effect Transistor arranged together with the step-up transformer to form a resonant step-up oscillator.
  • the dc-dc convertor may comprise an H bridge of transistors arranged under the control of control means for providing an input to the step up transformer and the self-start means may comprise an auxiliary source of power for the control means for allowing start up.
  • the harvesting module may comprise control means arranged to control the turns ratio of the step-up transformer to modify the load generated by the dc-dc converter.
  • a secondary winding of the step-up transformer may comprise a plurality of tappings and/or the step-up transformer may comprise a plurality of secondary windings and the control means may be arranged to select windings and/or tappings to provide a desired turns ratio.
  • the harvesting module may comprise at least a pair of terminals from which connection to the two spaced locations may be made.
  • the harvesting module may have more than two terminals, wherein each of the terminals is for allowing connection to a respective location and the harvesting module may further comprise switch means for selectively electrically connecting two of the terminals across the electrical circuit so allowing selection of which of the respective locations the electrical circuit is connected between.
  • the set up may include one lower connection and two upper connections at different locations. Once installed it may be determined that greater power can be harvested if a first of the upper connections is used so this first connection may be used. In another case the second upper connection may be better.
  • the switch might also be used dynamically in use to switch between connections.
  • the harvesting module may comprise an energy storage device for storing harvested power.
  • the energy storage device may comprise a charge storage device which may comprise at least one capacitor and/or re-chargeable battery.
  • the harvesting module may comprise variable impedance means for varying the load seen between the two connections.
  • variable impedance means may be microprocessor controlled.
  • the harvesting module may be arranged to use the variable impedance means to vary the load so as to optimise energy harvesting.
  • the harvesting module may be arranged to use the variable impedance means to modulate the load so as to communicate data away from the harvesting module.
  • the harvesting module may comprise a primary battery such that in use power may be selectively drawn from the power harvested by the circuit and from the primary battery.
  • the step of modulating the current may, amongst other things, comprise and the modulation means may, amongst other things, be arranged to:
  • Techniques i) and ii) are likely to only be available at an upper location, whereas technique iii) is likely to be available downhole and at an upper location.
  • Communication using this overall idea can be used for one way, say, surface to downhole communication, one way, say, downhole to surface communication and two way communication.
  • These techniques enable communication as part of a hybrid communication system - i.e. where some parts of the signal channel are provided by modulating the cathodic protection signals and some by other techniques, such as other wireless techniques including other EM techniques and acoustic techniques.
  • the cathodic protection may be provided by a passive cathodic protection system where sacrificial anodes are connected to metallic structure of the well installation or by an impressed cathodic protection system where a protective current is applied to metallic structure of the well installation.
  • the aim is to make use of existing cathodic protection systems (or other sources of current if available), in particular to make use of existing anodes where present in say subsea installations and without requiring modification thereto.
  • anodes where present will typically be outside, that is above, the bore hole and located in water.
  • the anodes will typically be remote from the location at which power and/or signalling is required.
  • any above system may include one or more of: at least one existing anode; at least one anode provided in water, say the body of water in which a subsea well installation is provided; at least one anode that is remote from the location at which power and/or signalling is to be achieved using current developed by that anode.
  • any system above may be arranged to enable the transmission of power from a location at which current, say CP current, is applied to the structure to a harvesting and/or signalling location.
  • current say CP current
  • the current is a passive CP current, an impressed CP current, or another applied current. That is to say typically, the source of the CP current or other current is remote from the harvesting and/or signalling location.
  • the metallic structure may be uninterrupted in the region of the at least one anode and/or the region of the harvesting module.
  • systems may comprise a primary battery for supplying power independently of harvested power.
  • the harvesting module may comprise the primary battery. Where a primary battery is provided this may be used preferentially whilst it holds power. It might be used for example to enable use of a higher date rate at an early stage, this being allowed to fall when only harvested power is available.
  • Figure 1 shows a well installation of an oil and/or gas well.
  • an oil and/or gas well may be a land well or a sub-sea well (meaning a well under any body of water) where the well head is underwater on the sea, river, lake etc. bed or on a platform.
  • the well installation is provided with a cathodic protection system. In the case of land wells this will most likely be in the form of an impressed current cathodic protection system where a protective current is applied to the metallic structure of the well.
  • the cathodic protection will most likely be a passive cathodic protection system where a plurality of anodes of a relatively reactive metal, such as a magnesium alloy, are connected to the metallic structure and exposed to the water in which the well installation is situated
  • a "well installation" in the present specification may be a water injection well.
  • Such a well will have a similar construction to the installations shown in more detail in this application.
  • the present techniques may be used whilst drilling as well as during production and following abandonment.
  • the well installation may be a partially complete installation where drilling is taking place. More generally the present techniques may be used during any period of the life cycle of a well installation.
  • the well installation shown in Figure 1 comprises a well head 1 and downhole metallic structure 2 leading down into the borehole of well from the surface S.
  • the well installation is provided with a cathodic protection system 3A, 3B.
  • this will either be an impressed current cathodic protection system 3A or a passive cathodic protection comprising a plurality of anodes 3B connected to the metallic structure of the well installation, that is to the well head 1 or other metallic components connected thereto.
  • the downhole metallic structure 2 comprises a first run of metallic pipe 21, that is, production tubing, running down into the borehole of the well. Around this is a first casing 22. Outside this layer is a second casing 23 and then a third casing 24. As will be appreciated there is a respective annulus between each run of metallic pipe. Thus there is a first annulus between the production tubing 21 and the first casing 22 commonly referred to as the "A" annulus in the oil and gas industry and indicated by reference numeral A in the drawings.
  • a second annulus exists between the first casing 22 and the second casing 23 commonly known as the "B" annulus and so indicated in the drawings and a third annulus exists between the second casing 23 and the third casing 24 commonly known as the "C” annulus and so indicated in the drawings.
  • Wells also typically can have a further, "D”, annulus, and sometimes even more annuli.
  • the metallic structure may comprise other elongate members, specifically, one or more of casing, liner, tubing, coiled tubing, sucker rod.
  • Monitoring apparatus provided in the well installation comprises an electrical power harvesting module 4 provided, in this embodiment, in the A annulus.
  • the harvesting module 4 is electrically connected via cables 41 to a pair of spaced locations 41a, 41b on the production tubing 21.
  • the harvesting module 4 may be electrically connected to one of the locations via a cable but may be electrically connected to the other location without a cable.
  • the harvesting module 4 may be electrically connected via a conductive housing of (or surrounding) the harvesting module to one of the locations. Thus only one such cable may need to exit the housing.
  • the metallic structure of the well is generally unaffected by the installation of this system. No insulation joints have been introduced into any of the runs of metallic pipe in order to make the system effective and the normal flow of cathodic protection current in the structure has not been altered - other than, of course, the harvesting which is taking place.
  • the run of metallic structure to which the connections are made is continuous, more generally all of the runs of metallic structure are continuous at these regions. This is not essential for operation, but it is possible and it is the normal prevailing situation in a well installation - ie the standard metallic structure of the installation has been left unchanged.
  • the current can and does flow in the same direction in the metallic structure in the region of the connections and between the connections.
  • the current flow might be in a single run of metallic structure to which the connections are made, or jump from one run to another or flow in parallel in several runs - the point is that an artificial arrangement of metallic structure in the well has not had to be set up to allow the system to work, and as such there is an uninterrupted current flow path provided by the metallic structure and current flow is in the same longitudinal direction in the metallic structure.
  • the monitoring apparatus further comprises a downhole gauge 5 which is provided deeper in the well than the harvesting module 4 and is connected thereto via a cable 42.
  • the downhole gauge 5 is provided just above a packer P.
  • the cables 41 connecting the harvesting module 4 to the production unit 21 will be tubing enclosed conductors (TEC) as typically used in the oil and gas industry and the cable 42 connecting the harvesting module 4 to the downhole gauge 5 will also be a tubing enclosed conductor (TEC).
  • TEC tubing enclosed conductors
  • the cross-sectional area of the conductor in the lengths of cable 41 connecting the harvesting module 4 to the production tubing 21 will have a larger cross-sectional area than that of the cable 42 connecting the harvesting module 4 to the downhole gauge 5.
  • the potential of the metallic structure of the well is taken to a sufficiently negative potential at the point of injection, say the well head 1, such as to suppress corrosion at the well head and at other points along the downhole metallic structure 2 as it descends into the well.
  • the magnitude of this negative potential will decrease as one progresses further down into the well due to the losses in the system. Therefore the potential of the metallic structure 2 near the well head will be more negative than at deeper locations in the well.
  • cathodic protection currents will be of the order of 10 Amps whereas the present systems might extract say 10-100 milli Amps.
  • the amount of current extracted is well within the tolerance usually allowed for when developing cathodic protection systems. If desired an increased level of impressed current can be provided or the number of anodes provided could be increased beyond the norm. This would increase the cathodic protection current and hence improve harvesting.
  • Electrical power may be harvested from the system at the downhole location of the harvesting module 4 and this harvested power may be used for other purposes.
  • this harvested power is used to power the downhole gauge 5 and allow extraction of readings therefrom and communication of those readings to the surface S.
  • an upper communication unit 6 is provided for communicating with the harvesting module 4 and downhole gauge 5.
  • the upper communication unit 6 is provided at the surface S - in this case the land surface.
  • monitoring may be of reservoir pressure where desired or similarly of the pressure in an enclosed annulus to, for example, help detect any leak, issue, or failure in the system.
  • the sensor and harvesting module may be located in the enclosed annulus, in such a case.
  • monitoring the pressure in an enclosed annulus may permit production at higher rates than those achievable if modelling of the expected pressure rise alone is used as use of modelled pressure would require greater safety margins and potentially correspondingly reduced production rates.
  • the present techniques can facilitate such monitoring and/or control.
  • Another particular implementation of the present techniques will include a sensor module located in the same location as is most usual for a conventional permanent downhole gauge and provided for the same purpose as is most usual for a conventional permanent downhole gauge.
  • the sensor module may be disposed in the A annulus and arranged for monitoring the reservoir pressure by sensing the pressure in the tubing via a pressure communication port through the tubing so allowing inference of the reservoir pressure based on the sensed pressure and taking into account static pressure and flow effects.
  • reservoir pressure will generally be inferred in this way rather than directly measured - positioning a sensor directly in the reservoir is generally not feasible - as will also be appreciated "monitoring reservoir pressure" covers use of such measurement techniques.
  • a harvesting module may also be provided at the location of the sensor module.
  • the harvesting module 4 is arranged to accept a signal from the downhole gauge which is indicative of the parameter to be measured, for example, pressure and/or temperature and to transmit this data towards the surface by virtue of modulating the load which the harvesting module 4 creates between the spaced connections 41a and 41b.
  • this change in load will change the amount of current drawn from the cathodic protection currents applied to the system.
  • This is detectable at the surface or other convenient location by the virtue of a change in the potential of the metallic structure at the surface or the other convenient location. It may be detected by detecting for example, the change in potential at the well head 1 or by detecting the voltage across, or a current seen by, a power supply used in an impressed cathodic protection system 3A.
  • the effect of the modulation is detected by the upper communications unit 6, monitoring the potential of the well head relative to a reference earth, to extract the pressure and/or temperature measurement data.
  • the spacing between the spaced connections 41a, 41b is at least 100 metres and more likely in the region of 300 to 500 metres.
  • the optimal spacing for the spaced connections 41a, 41b may be determined by modelling for a given installation. As the distance between these connections is increased this tends to increase potential difference between the connections (although the rate of increase of potential difference decreases as the depth of the lower connection is increased). On the other hand, as the spacing increases the total length and hence resistance of the cables 41 increases. Thus in most systems there will be an optimal spacing.
  • FIG 2A shows the harvesting module 4 of the apparatus shown in Figure 1 in more detail.
  • the harvesting module 4 has a pair of terminals 43a, 43b to which the respective cables 41 are connected. There is galvanic connection between the metallic structure and the terminals 43a, 43b. Connected between these terminals 43a, 43b is a low voltage dc to dc converter for harvesting the electrical energy where potential difference is seen across the terminals 43a, 43b.
  • the dc to dc converter 44 is connected to a charge storage means 45 including at least one low leakage capacitor and connected to and controlled by a microprocessor driven central unit 46.
  • the charge storage means 45 and central unit 46 are also connected via a respective terminal 43c to the length of cable 42 which leads to the downhole gauge 5.
  • the charge storage means 45 might be dispensed with -ie: enough power might be harvested to allow continuous operation as and when required.
  • the central unit 46 controls the operation of the dc to dc converter 44 so as to optimise the load which it presents to the current seen by the harvesting module 4 due to the cathodic protection currents in order to maximise the energy which may be harvested and used or stored in the charge storage means 45.
  • the central unit may be arranged to selectively use and/or deliver harvested energy directly when appropriate, and store energy and extract stored energy when appropriate.
  • microprocessor driven central unit 46 may be replaced by alternative electronics including say an analogue feedback circuit, or a state machine or even a fixed harvesting load based on modelling for the particular installation.
  • the central unit 46 When stored energy is to be used, power from the charge storage means 45 is fed via the cable 42 to the downhole gauge 5 and readings from the downhole gauge 5 are acquired by the central unit 46 via the cable 42.
  • the central unit 46 also controls operation of the dc to dc converter 44 to modulate the load which is introduced between the terminals 43a and 43b in order to send signals back to the surface carrying readings from the downhole gauge 5 as described above.
  • the dc to dc converter 44 and central unit 46 together act as a variable impedance means by virtue of the central unit 46 controlling the operation of the dc to dc converter 44 to introduce variable impedance between the terminals 43a and 43b.
  • an appropriate sensor may be provided at the same location as the harvesting module 4.
  • a downhole unit 4a as shown in Figure 2B may be provided which comprises both a harvesting module 4 and at least one downhole device to be powered.
  • the downhole unit 4a includes a pressure sensor 47 and a communications unit 48.
  • the downhole unit 4a might still be used to power an external device even if including its own sensor 47 and/or communications unit 48 and thus there might be a secondary cable 42.
  • the downhole unit 4a might use its own communications unit 48 for communicating back towards the surface. Such communication might be in the form of the EM communication signals which may be applied back to the downhole metallic structure 21 via the cables 41.
  • the communications unit 48 provided in the downhole unit 4a might be an acoustic communications unit for applying acoustic signals to the metallic structure 21 for transmission back towards the surface. In such a case then an upper communications unit would be arranged for receiving acoustic signals.
  • two way communication may be provided as and when desired over any or all parts of the communications channels. Further two communication techniques may be used parallel in any leg of the communications channels - thus EM signals and acoustic signal might be used side by side.
  • the harvesting module 4 or downhole unit 4a may comprise at least one power converter for controlling the voltage at which the power is harvested for delivery to the charge storage means 45 and/or other components such as the central unit 46. It may be desirable to store energy at a different voltage than that at which it is harvested and/or different from that at which it is used by the central unit 46 or other components. For example, it may be desirable to store the power at a higher voltage than that at which it is harvested and/or consumed. This can be useful, for example, if there is a large draw on the stored power during for example transmission.
  • a possible implementation for a dc to dc convertor is to use a commercially available integrated circuit.
  • An alternative is to produce a similar circuit using discrete components.
  • a dc to dc convertor that can cope with low input voltages is desirable.
  • One way to achieve this is to use a Field Effect Transistor, such as JFET switch, to form a resonant step-up oscillator using a step-up transformer and a coupling capacitor.
  • the turns ratio on the transformer may be selected, preferably dynamically selected during operation.
  • a plurality of tappings may be provided on the secondary of the transformer which may be selectively used to provide respective turns ratios.
  • a processor such as that of the central unit may be arranged to control a switch to dynamically select the respective tappings and hence control the load generated by the dc-dc convertor.
  • FIG. 2C shows a schematic circuit diagram for a possible implementation of a resonant step-up oscillator of the type described above.
  • the available input potential difference may be connected across the input terminals as Vin and the output Vout is seen across the output terminals.
  • the circuit comprises a Field Effect Transistor 201, a step up transformer 202 which together act as an oscillator and a rectifying output arrangement 203 comprising a crossed diode pair 206 and respective coupling capacitors 205.
  • a primary winding 202a of the transformer 202 is connected in series with the FET 201 and the input Vin is applied across these.
  • the gate of FET 201 is connected to the secondary winding 202b of the transformer 202.
  • the output Vout is seen across the coupling capacitors 205 which are each connected across the secondary winding 202b via the respective diodes 204.
  • the secondary winding 202b of the transformer 202 comprises a plurality of tappings 202c which can be selected using switch 206 so allowing adjustment of the turns ratio.
  • the switch 206 can be controlled by a microprocessor, in this case the central unit 4b.
  • This type of dc to dc convertor arrangement is able to function even when the potential difference seen across the terminals (input voltage) is low, that is 0.5V or below.
  • the input voltage may be less than 0.25V and perhaps even less than 0.05V.
  • semiconductor band gap voltages say 0.7V
  • many types of dc to dc convertors will not function to allow energy harvesting at such input voltages.
  • dc to dc convertors based on the above principles can function at even such low voltages.
  • Such a dc to dc convertor can be considered to include start up means arranged to allow operation when the input voltage is 0.5V or below as well as at higher voltages.
  • An alternative approach is to provide a circuit with a separate power source to act as part of a start up means.
  • a primary battery may be provided to start up the system after installation.
  • stored energy in an energy store might be used to restart the system if energy harvesting temporarily stops.
  • FIG. 2D shows a schematic circuit diagram for a possible implementation of a dc to dc convertor operating on such a basis.
  • the dc to dc convertor of Figure 2D comprises an H bridge 207 of transistors 207a across which the input voltage is connected.
  • the gates of the transistors 207a are connected to a control unit 208 which is arranged to control the switching of the transistors 207a to generate an ac output.
  • the ac output of the H bridge 207 is connected across a primary winding 202a of a step up transformer 202.
  • the secondary winding 202b of the transformer 202 is connected to a rectifier 209.
  • One output of the rectifier 209 is connected via a diode 204 to the input of a power supply unit 210 and the other output is connected to ground. Also connected to the input of the power supply unit 210 via another diode 204 is a battery 211.
  • the power supply unit 210 is arranged to power the control unit 208. In order to start up operation the power supply unit 210 may use power from the battery 211. Once energy is being harvested by the dc to dc convertor then the power supply unit 210 may use power received from the rectifier 209 - ie harvested power.
  • harvested energy may also be stored in a storage means and used from the storage means.
  • the storage means may, for example, include at least one low leakage capacitor and/or at least one rechargeable cell. Where energy is stored this allows a mechanism to restart the system if harvesting is ceased at any point after the battery 211 has discharged.
  • the battery 211 may be a primary (one shot) battery, or may be a re-chargeable battery provided it is charged at the time of installation. Where the battery is a re-chargeable battery, in some implementations the power supply unit 210 may be arranged to store energy in it when available, alternatively it may be more convenient to provide a separate energy storage means (which might include a rechargeable battery).
  • a dc to dc convertor of the type shown in Figure 2D may be arranged to allow control of the load generated by the dc to dc convertor.
  • a similar arrangement to that shown in Figure 2C may be used where the secondary winding 202b has multiple tappings and a switch is provided to allow selection of the tappings. This switch could sit between the windings and the input to the rectifier 209.
  • separate secondary windings could be provided rather than multiple tappings, to achieve a similar result.
  • the switch can be controlled by a control unit as in the case of the arrangement of Figure 2C .
  • harvesting module 4 and downhole gauge 5 may be provided in other annuli within the well installation rather than the A annulus. Further the gauge may be arranged to sense a parameter in a different annulus than the one in which it is located.
  • these components may be provided in the B or C annulus and a gauge located in say the B annulus may be arranged to sense one or more parameter in the A annulus, the B annulus, the C annulus or any combination thereof. It is noted that these are locations where it is generally not possible, or at least undesirable, to try to provide direct cable connections from the surface.
  • the present techniques give rise to the possibility of monitoring say pressure in the B or C annulus for the life of a well installation where this would be difficult and/or expensive using conventional power delivery methods.
  • the present techniques avoid the use of penetrators through the well head which can reduce risk and cost. They also provide relatively simple, neat and easy to install solutions.
  • Figure 3 shows a well installation similar to that of Figure 1 but including a downhole communications repeater 7 rather than a downhole gauge.
  • the repeater 7 is provided in the B annulus along with a harvesting module 4 of the same type described above in relation to Figures 1 , 2A to 2D .
  • the harvesting module 4 harvests power from the cathodic protection currents in the metallic structure 2 and provides this power to the downhole communications repeater 7.
  • the downhole component delivered power by the power delivery system is a communications repeater 7 rather than the downhole gauge 5.
  • the downhole communications repeater 7 is arranged to pick up signals from the downhole metallic structure 2 in the region of the repeater 7 and transmit the relevant data onwards towards the surface.
  • the signals are applied to the downhole metallic structure 2 as EM signals by a transmission tool 71 located further down in the well, for example in the production tubing 21.
  • the repeater 7 is arranged to pick up EM signals.
  • a different type of transmission tool may be provided for sending signals which are picked up by the repeater.
  • a tool may, for example, be disposed outside of the tubing.
  • the communications repeater 7 may be arranged to pick acoustic signals from the downhole metallic structure 2 which have been applied further downhole.
  • the downhole communications repeater 7 may be arranged to apply acoustic signals to the downhole structure 2 for transmission towards the surface or arranged to apply EM signals to the downhole metallic structure 2 for transmission to the surface or to make use of the impedance modulation signalling technique described above.
  • the communications repeater 7 may pick up signals at its location and transmit these along the cable 42 to the harvesting module 4 by applying signals thereto or by modulating the load which it puts on the power supply in the harvesting module 4.
  • the harvesting module 4 may be arranged to apply signals to metallic structure 2 for transmission towards the surface or be arranged to modulate the load which it generates between the spaced connections 41a, 41b for detection at the surface by the upper communication unit 6.
  • EM signals may, for example, be picked up and/or applied by the repeater 7 using spaced contacts made to the metallic structure, or using an inductive coupling comprising a toroid or signalling across an insulation joint should one be available and so on.
  • conventional acoustic signal pick up and application techniques may be used.
  • the repeater 7 may act as a repeater in both directions. Again two communication techniques may be used in parallel on at least one leg of the channel to provide redundancy.
  • downhole communications repeater 7 may be provided in a location such as not to be in the product flow whilst allowing life of well operation.
  • the repeater 7 maybe provided in a downhole unit with the harvesting module, or be separate therefrom. Again the repeater may be a two way repeater.
  • the devices may be arranged to manage the power budget, i.e. use less energy overall, by using intermittent operation of the components such as EM or acoustic receivers and/or transmitters.
  • Figure 4 schematically shows a well installation including a remotely controlled valve and a power delivery system of the same general type as described above.
  • the well installation comprises a first hydraulically operated sub-surface safety valve SSSV provided in the production tubing 21 as is conventional.
  • an additional subsurface safety valve 8 is provided also within the production tubing 21, but further down in the well.
  • the second subsurface safety valve 8 is provided as an additional safety or fallback measure.
  • the hydraulically operated subsurface safety valve SSSV could be dispensed with.
  • the second subsurface safety valve 8 is powered and operated by making use of a power delivery system.
  • a harvesting module 4 is connected to the second sub-surface safety valve 8 via a cable 42 and the harvesting module is arranged to issue power and control signals to the second subsurface safety valve 8 via the cable 42.
  • energy is harvested from the cathodic protection currents running in the downhole structure 2 and this is used to both control and operate the second subsurface safety valve 8.
  • Such a subsurface safety valve 8 may be located deeper into the well than a traditional hydraulically operated subsurface safety valve SSSV. This is because it is not subject to the same range limits as hydraulically driven systems - there is no requirement to drive hydraulic fluid to it.
  • control signals for the second subsurface safety valve 8 may be transmitted by the upper communications unit 6 via the metallic structure of the well 1, 2 for detection by the harvesting module 4 and onwards transmission to the subsurface safety valve 8.
  • the valve 8 may be caused to operate in a fail safe mode such that the valve will close in the absence of power and/or control signals.
  • the valve 8 and harvesting module might be provided as part of a common downhole tool 4a. Further in some cases power for closing the valve may come from another source, with the downhole power delivery system supplying power for controlling operation and/or operating a trigger mechanism.
  • Figure 5 shows an alternative well installation including well monitoring apparatus.
  • a harvesting module 4 provided within the downhole metallic structure 2 and connected to spaced locations on the downhole structure 2 and moreover there is a downhole gauge 5 connected to the harvesting module 4.
  • the harvesting module 4 and downhole gauge 5 are both provided in the B annulus to provide monitoring of conditions in this annulus.
  • the downhole gauge 5 may, for example, comprise a pressure and/or temperature sensor.
  • the spaced locations 41a, 41b are provided on different runs of the downhole metallic structure 2.
  • a first of the connections 41a is made to the second casing 23 whilst the other of the connections 41b is made to the first casing 22.
  • the system works on a similar principle as discussed above and therefore relies on a potential difference existing between these two connections 41a, 41b.
  • this potential difference is realised by virtue of insulating the two runs of metallic structure 22, 23 from one another in at least the region of these connections. This means that there is a different passage to earth for the cathodic protection currents from the two runs of metallic structure 22, 23.
  • the means of insulating the two runs of metallic structure 22, 23 from one another comprise an insulating coating 91 provided on the outer surface of the first casing 22 and a plurality of insulating centralisers 92 provided on the first casing 22 to keep this separated from the second casing 23.
  • this insulation 91 and these centralisers 92 will be provided over a length of the first casing 22 of at least 100 metres and more likely 300 to 500 metres.
  • insulating spacers may be mounted on the outer run of metallic structure forming the annulus.
  • the insulation need not be entirely continuous to provide a useful effect.
  • the creation of a different path to earth is the aim.
  • the insulation may be provided over 100m, it may not be continuous, or provide continuous insulation over this distance.
  • the benefit of the arrangement shown in Figure 5 is that the long lengths of cable 41 between the harvesting module 4 and the metallic structure 2 required in the arrangement shown in Figure 1 can be dispensed with.
  • the system may be easier to install.
  • the system may be deployed by virtue of a housing for the harvesting module 4 being mounted on a piece of metallic pipe and provided with a sliding contact for contacting another piece of pipe across the annulus.
  • the downhole gauge 5 may be dispensed with and a sensor provided along with the harvesting module 4 in a downhole unit 4a. Such an arrangement can reduce rig time required for installation.
  • the provision of the insulation means 91, 92 may be preferable to the provision of the cables 41.
  • Which system is preferable for a given installation may be determined by external factors concerning the installation or perhaps by modelling the particular installation.
  • a communications repeater 7 and associated power delivery system may be provided when a well is first installed to make the well wireless ready. This will facilitate communication to the surface if at a later time it is decided to use, for example, a downhole wireless signalling tool 71 to signal to the surface.
  • a downhole wireless signalling tool 71 to signal to the surface.
  • the present systems may be retro-fitted.
  • a system such as that shown in Figure 1 installed in the A annulus may be retro-fitted when production tubing is replaced.
  • a system could be installed in the main bore of the production tubing. Note that importantly each of the arrangements and techniques described in the present specification avoid the need for a cable to penetrate through the well head 1. Thus these systems can be used where no penetrator is available or the use of one is unattractive.
  • FIG. 4 Whilst the arrangement in Figure 4 shows the provision of an additional subsurface safety valve 8, in other circumstances a different type of (possibly remotely operated) valve or component may be provided.
  • an arrangement of the type shown in Figure 4 may be used with an annulus vent valve provided in a well to allow controlled fluid communication or venting between one annulus and another or between an annulus and the bore.
  • the valve could comprise a gas lift injection valve for allowing gas into the bore of production tubing from the A annulus.
  • the valve may be a packer, a through packer valve or a packer by-pass valve. Again for allowing venting of a particular annulus under control from the surface.
  • valve may comprise a flow control valve to either control contribution from a zone or provide a means to enable improved pressure build up data capture by removing the effect of well bore storage.
  • valve in each case may be flow control device which may not allow complete shutting off of flow but say act as a variable choke.
  • valve or component in each case may be a wirelessly controlled valve or component.
  • the present techniques may be used for communication with and/or control of a tool supported by a wireline/slick line or attached to coiled tubing in the production tubing 21. That is to say, such a tool may be arranged to apply signals to and/or pick up signals from the tubing which signals pass through the repeater 7.
  • a plurality of harvesting modules of any of the types described above may be provided in one well installation.
  • a gauge may be provided to monitor conditions in the production tubing
  • a gauge may be provided to monitor an annulus
  • a valve may be provided, all of which have power supplied from a separate respective harvesting module.
  • any one harvesting module may be used to power a plurality of devices.
  • each device may have dedicated cable from the harvesting module.
  • there may be a multi-drop system where one cable from the harvesting module is used to connect to a plurality of downhole devices.
  • the multi-drop system may be arranged to allow power delivery and communications with the plurality of downhole devices.
  • the cable may carry power signals, communication data and addressing data.
  • the harvesting module may be arranged to administer the multi-drop system.
  • cables 41, 42 run within unobstructed annuli, in other cases one or more of the cables 41, 42 may pass through a packer (including a swell packer), cement or other annular sealing device.
  • a packer including a swell packer
  • cement or other annular sealing device
  • the harvesting module may be provided in a plurality of separate parts, components, or sub-modules that may be differently located.
  • Figure 6 shows an alternative well installation which has similarity with the installation shown in Figure 1 and the same reference numerals are used to indicate the features in common with the embodiment of Figure 1 and detailed description of these common features is omitted.
  • the well installation includes monitoring apparatus in the same way as Figure 1 .
  • a harvesting module 4 connected via cables 41 to a pair of spaced locations 41a and 41b.
  • a first of the locations 41a is on the production tubing 21 and thus a first of the cables 41 is connected to the production tubing whilst the second of the spaced locations 41b is on the casing 22.
  • insulation 91 is provided on the production tubing 21 in the region of the second connection 41b and extends axially either side of this.
  • one connection might be to the formation rather than to the metallic structure.
  • all of the apparatus of the power delivery system could be provided outside of the casing - i.e. between the casing and formation. This will generally be undesirable from a risk/difficulty in installation point of view, but is a possibility.
  • each of these other harvesting modules 4', 4" makes use of the same first cable 41 and as such one terminal of each of the harvesting modules 4', 4" is connected to the first connection point 41a.
  • separate cables could be used for making these connections to the first connection point and this would be preferable leading to improved performance.
  • a plurality of harvesting modules may be provided which are distributed across different annuli.
  • the first harvesting module 4 is connected via a secondary cable 42 to a downhole gauge 5 similarly to the embodiments shown in Figure 1 .
  • the downhole gauge 5 is located below a packer P and the cable 42 passes therethrough.
  • the gauge 5 in this case is arranged for taking pressure and/or temperature measurements of conditions inside the production tubing 21 through a port 21a provided in the wall of the production tubing 21. That is to say although the downhole gauge 5 is provided in the "A" annulus it is arranged for measuring parameters within the production tubing 21.
  • second and third downhole gauges 5' and 5" are provided.
  • each of the downhole gauges 5, 5', 5" is connected to the harvesting module 4 via the same secondary cable 42.
  • the cable 42 is used for carrying power signals, control signals, parameter data and addressing data to allow powering of each of the gauges 5, 5', 5" as well as extracting readings therefrom.
  • a number of downhole gauges or other downhole devices may be powered from one harvesting module 4 via individual dedicated cables 42 rather than a single cable as in the present embodiment.
  • one harvesting module may be used for powering different types of downhole device.
  • one harvesting module for example, might be used to power a downhole gauge, a downhole repeater and a downhole valve.
  • the second harvesting module 4' is part of a downhole tool which comprises both a harvesting module and a sensor.
  • the sensor is arranged for measuring parameters in the "B" annulus via a port 22a provided in the first casing 22.
  • the sensor in the second harvesting module 4' may be arranged from measuring pressure and/or temperature in the "B" annulus.
  • the third harvesting module 4" is again part of a downhole tool comprising, in this case, the harvesting module and a communication unit for communicating with sensors 605 provided in the "B" annulus and the "C” annulus.
  • communication between the sensors 605 and the second harvesting module 4" is via wireless means.
  • the sensors 605 may be placed physically as close as possible to the harvesting module 4".
  • data may also be sent from the desk location D to the upper communication unit 6 for transmission downhole.
  • control signals may be transmitted from a desk location D via the upper communications unit 6 downhole to control operation of a harvesting module or sensor or downhole valve or repeater or so on and similarly any desired data may be sent in this fashion downhole.
  • insulation may be provided on the outside of the outermost casing, for example, the third casing 24 in the embodiment shown in Figure 6 in the region near the well head 1. This can help drive the maximum negative potential caused by the cathodic protection currents further down into the well. This is by virtue of minimising the leakage in this region near the well head.
  • providing insulation on the outermost casing can help allow the uppermost connection 41a to be positioned lower in the well without significantly reducing the effectiveness of the system. If one considers the potential decay curve, then by providing insulation on the outermost casing 24, the negative potential will decay very slowly in the insulated region near the well head and then begin to decay more quickly once the uninsulated region has been reached.
  • Figure 7 is a plot showing an example of how the optimal power available for harvesting in a well installation varies with depth in the well.
  • the plot shown in Figure 7 relates to a position where the upper connection 41a is approximately 5 metres below the well head and thus in the region of the liner hanger. In this example it can be seen that the optimum depth of the lower connection is in the order of 550 metres down in the well.
  • the optimal location for the upper connection may depend on the where the CP current (or other current) is injected and where the current is a maximum, or the potential caused by the current is a maximum.
  • the present methods and systems may include steps of first determining where the applied current (or potential) has maximum magnitude and choosing the location for the upper connection in dependence on this.
  • the upper connection may be within 100m of the surface, preferably within 50m.
  • the upper connection may be within 100m of the mudline, preferably within 50m.
  • the cable or cables 41 used in connecting the harvesting module to the structure/surroundings may have a cross-sectional area of say 10mm 2 to 140mm 2 .
  • 10mm 2 might be considered a low end of a desired operational cable size. Larger cross-sectional area would normally be preferable.
  • a 140mm 2 cable might be Kerite (RTM) LTF3 flat type cable. This represents the upper end of what is currently commercially available, but, if available, larger sizes can be used.
  • Figure 8 is a flow chart showing a process for optimising the energy harvesting of a harvesting module of the type described above.
  • step 801 the dc to dc convertor 44 initiates using initial settings/configuration and delivers available energy to the charge storage means 45.
  • step 802 a determination is made as to whether there is sufficient voltage to power the microprocessor in the central unit 46. If no, this step 802 repeats until the answer is yes and when the answer is yes, the process proceeds to step 803 where the microprocessor in the central unit 46 is powered.
  • step 804 the microprocessor measures the power output from the energy harvester and in step 805 the microprocessor modifies the dc to dc convertor 44 settings to slightly increase load. Subsequently in step 806, a determination is made as to whether this leads to an increase in harvester output. If the answer is yes then the process returns to before step 805 so that the dc to dc convertor 44 settings can be altered again to slightly increase load.
  • step 806 determines whether this has resulted in an increase in output.
  • steps 805, 806 and 807 are repeated iteratively during energy harvesting such that the load is successively incremented and decremented based on the result in step 806.
  • steps 805, 806 and 807 are repeated iteratively during energy harvesting such that the load is successively incremented and decremented based on the result in step 806.
  • the step of changing the dc to dc convertor settings in steps 805 and 807 may comprise the step of changing the tapping used on the secondary transformer in order to modify the load appropriately.
  • a variable transformer is provided with a H-bridge as shown in Figure 2D .
  • the duty cycle of the transistors in the H-bridge may be adjusted to vary the load.
  • Figure 9 shows a flow chart illustrating operation of a downhole unit 4a of the type described above.
  • step 901 it is determined whether there is sufficient power to power the processor in the central unit 46. If not the process stays at this step until there is sufficient power.
  • step 902 it is determined whether a command has been received or there is a requirement to send a scheduled set of data. If not then the process remains in this state of determining whether any action is required until action is required.
  • step 903 data is recovered from a sensor or from memory as required and the load presented by the energy harvester module between the connections 41a is modulated to encode data.
  • step 904 the voltage potential of the well head is monitored and data is decoded in a second microprocessor. Then in step 905 the extracted data may be exported or retransmitted to a client e.g. through a seawater acoustic link or an umbilical link.
  • Figure 10 shows a well installation including a platform 1000.
  • the well head 1 is provided on a deck 1001 of the platform 1000.
  • the metallic structure includes a riser 1002 between the mudline and the deck 1001.
  • the production tubing 21 runs within the riser 1002 as well as downhole.
  • Casing 22, 23, is provided downhole.
  • the innermost casing 22 is a continuation of the riser 1002.
  • Cathodic protection anodes 3B are provided on the platform structure 1000. Electrical connection will exist between the platform and the downhole structure 2 (casing and production tubing). This may be via a drilling template 1003 and/or via the well head, riser and other components such as riser guides.
  • wireless signals may be transmitted in at least one of the following forms: electromagnetic, acoustic, inductively coupled tubulars and coded pressure pulsing and references herein to "wireless”, relate to said forms, unless where stated otherwise.
  • Control signals can control downhole devices including sensors. Data from sensors may be transmitted in response to a control signal. Moreover data acquisition and/or transmission parameters, such as acquisition and/or transmission rate or resolution, may be varied using suitable control signals.
  • Pressure pulses include methods of communicating from/to within the well/borehole, from/to at least one of a further location within the well/borehole, and the surface of the well/borehole, using positive and/or negative pressure changes, and/or flow rate changes of a fluid in a tubular and/or annular space.
  • Coded pressure pulses are such pressure pulses where a modulation scheme has been used to encode commands and/or data within the pressure or flow rate variations and a transducer is used within the well/borehole to detect and/or generate the variations, and/or an electronic system is used within the well/borehole to encode and/or decode commands and/or the data. Therefore, pressure pulses used with an in-well/borehole electronic interface are herein defined as coded pressure pulses.
  • An advantage of coded pressure pulses, as defined herein, is that they can be sent to electronic interfaces and may provide greater transmission rate and/or bandwidth than pressure pulses sent to mechanical interfaces.
  • coded pressure pulses are used to transmit control signals
  • various modulation schemes may be used to encode control signals such as a pressure change or rate of pressure change, on/off keyed (OOK), pulse position modulation (PPM), pulse width modulation (PWM), frequency shift keying (FSK), pressure shift keying (PSK), amplitude shift keying (ASK), combinations of modulation schemes may also be used, for example, OOK-PPM-PWM.
  • Transmission rates for coded pressure modulation schemes are generally low, typically less than 10bps, and may be less than 0.1 bps.
  • Coded pressure pulses can be induced in static or flowing fluids and may be detected by directly or indirectly measuring changes in pressure and/or flow rate. Fluids include liquids, gasses and multiphase fluids, and may be static control fluids, and/or fluids being produced from or injected in to the well.
  • Wireless signals may be such that they are capable of passing through a barrier, such as a plug or said annular sealing device, when fixed in place. Therefore wireless signals may be transmitted in at least one of the following forms: electromagnetic, acoustic, and inductively coupled tubulars.
  • EM/Acoustic and coded pressure pulsing use the well, borehole or formation as the medium of transmission.
  • the EM/acoustic or pressure signal may be sent from the well, or from the surface. If provided in the well, an EM/acoustic signal may be able to travel through any annular sealing device, although for certain embodiments, it may travel indirectly, for example around any annular sealing device.
  • Electromagnetic and acoustic signals are useful as they can transmit through/past an annular sealing device without special inductively coupled tubulars infrastructure, and for data transmission, the amount of information that can be transmitted is normally higher compared to coded pressure pulsing, especially receiving data from the well.
  • inductively coupled tubulars there are normally at least ten, usually many more, individual lengths of inductively coupled tubular which are joined together in use, to form a string of inductively coupled tubulars. They have an integral wire and may be formed tubulars such as tubing, drill pipe, or casing. At each connection between adjacent lengths there is an inductive coupling.
  • the inductively coupled tubulars that may be used can be provided by N O V under the brand Intellipipe ® .
  • EM/acoustic or pressure wireless signals can be conveyed a relatively long distance as wireless signals, sent for at least 200m, optionally more than 400m or longer which is a clear benefit over other short range signals.
  • Inductively coupled tubulars provide this advantage/effect by the combination of the integral wire and the inductive couplings. The distance travelled may be much longer, depending on the length of the well.
  • Data and commands within signals may be relayed or transmitted by other means.
  • the wireless signals could be converted to other types of wireless or wired signals, and optionally relayed, by the same or by other means, such as hydraulic, electrical and fibre optic lines.
  • signals may be transmitted through a cable for a first distance, such as over 400m, and then transmitted via acoustic or EM communications for a smaller distance, such as 200m.
  • they may be transmitted for 500m using coded pressure pulsing and then 1000m using a hydraulic line.
  • Non-wireless means may be used to transmit the signal in addition to the wireless means.
  • the distance travelled by signals is dependent on the depth of the well, often the wireless signal, including repeaters but not including any non-wireless transmission, travel for more than 1000m or more than 2000m.
  • Different wireless signals may be used in the same well for communications going from the well towards the surface, and for communications going from the surface into the well.
  • Wireless signals may be sent to a communication device, directly or indirectly, for example making use of in-well relays above and/or below any annular sealing device.
  • a wireless signal may be sent from the surface or from a wireline/coiled tubing (or tractor) run probe at any point in the well optionally above any annular sealing device.
  • Acoustic signals and communication may include transmission through vibration of the structure of the well including tubulars, casing, liner, drill pipe, drill collars, tubing, coil tubing, sucker rod, downhole tools; transmission via fluid (including through gas), including transmission through fluids in uncased sections of the well, within tubulars, and within annular spaces; transmission through static or flowing fluids; mechanical transmission through wireline, slickline or coiled rod; transmission through the earth; transmission through wellhead equipment. Communication through the structure and/or through the fluid are preferred.
  • Acoustic transmission may be at sub-sonic ( ⁇ 20 Hz), sonic (20 Hz - 20kHz), and ultrasonic frequencies (20kHz - 2MHz).
  • sonic 20Hz - 20khz
  • ultrasonic frequencies 20kHz - 2MHz.
  • the acoustic transmission is sonic (20Hz - 20khz).
  • Acoustic signals and communications may include Frequency Shift Keying (FSK) and/or Phase Shift Keying (PSK) modulation methods, and/or more advanced derivatives of these methods, such as Quadrature Phase Shift Keying (QPSK) or Quadrature Amplitude Modulation (QAM), and preferably incorporating Spread Spectrum Techniques. Typically they are adapted to automatically tune acoustic signalling frequencies and methods to suit well conditions.
  • FSK Frequency Shift Keying
  • PSK Phase Shift Keying
  • QPSK Quadrature Phase Shift Keying
  • QAM Quadrature Amplitude Modulation
  • Spread Spectrum Techniques Typically they are adapted to automatically tune acoustic signalling frequencies and methods to suit well conditions.
  • Acoustic signals and communications may be uni-directional or bi-directional.
  • Piezoelectric, moving coil transducer or magnetostrictive transducers may be used to send and/or receive the signal.
  • Electromagnetic (EM) (sometimes referred to as Quasi-Static (QS)) wireless communication is normally in the frequency bands of: (selected based on propagation characteristics)
  • Sub-ELF and/or ELF are useful for communications from a well to the surface (e.g. over a distance of above 100m). For more local communications, for example less than 10m, VLF is useful. The nomenclature used for these ranges is defined by the International Telecommunication Union (ITU).
  • ITU International Telecommunication Union
  • EM communications may include transmitting communication by one or more of the following: imposing a modulated current on an elongate member and using the earth as return; transmitting current in one tubular and providing a return path in a second tubular; use of a second well as part of a current path; near-field or far-field transmission; creating a current loop within a portion of the well metalwork in order to create a potential difference between the metalwork and earth; use of spaced contacts to create an electric dipole transmitter; use of a toroidal transformer to impose current in the well metalwork; use of an insulating sub; a coil antenna to create a modulated time varying magnetic field for local or through formation transmission; transmission within the well casing; use of the elongate member and earth as a coaxial transmission line; use of a tubular as a wave guide; transmission outwith the well casing.
  • a modulated current on an elongate member and using the earth as return; creating a current loop within a portion of the well metalwork in order to create a potential difference between the metalwork and earth; use of spaced contacts to create an electric dipole transmitter; and use of a toroidal transformer to impose current in the well metalwork.
  • a number of different techniques may be used. For example one or more of: use of an insulating coating or spacers on well tubulars; selection of well control fluids or cements within or outwith tubulars to electrically conduct with or insulate tubulars; use of a toroid of high magnetic permeability to create inductance and hence an impedance; use of an insulated wire, cable or insulated elongate conductor for part of the transmission path or antenna; use of a tubular as a circular waveguide, using SHF (3 GHz to 30GHz) and UHF (300MHz to 3GHz) frequency bands.
  • SHF 3 GHz to 30GHz
  • UHF 300MHz to 3GHz
  • Various means for receiving a transmitted signal can be used, these may include detection of a current flow; detection of a potential difference; use of a dipole antenna; use of a coil antenna; use of a toroidal transformer; use of a Hall effect or similar magnetic field detector; use of sections of the well metalwork as part of a dipole antenna.
  • elongate member for the purposes of EM transmission, this could also mean any elongate electrical conductor including: liner; casing; tubing or tubular; coil tubing; sucker rod; wireline; drill pipe; slickline or coiled rod.
  • Gauges can comprise one or more of various different types of sensor.
  • the or each sensor can be coupled (physically or wirelessly) to a wireless transmitter and data can be transmitted from the wireless transmitter to above the annular sealing device or otherwise towards the surface.
  • Data can be transmitted in at least one of the following forms: electromagnetic, acoustic and inductively coupled tubulars, especially acoustic and/or electromagnetic as described herein above.
  • Such short range wireless coupling may be facilitated by EM communication in the VLF range.
  • the sensors provided may sense any parameter and so be any type of sensor including but not necessarily limited to, such as temperature, acceleration, vibration, torque, movement, motion, cement integrity, pressure, direction and inclination, load, various tubular/casing angles, corrosion and erosion, radiation, noise, magnetism, seismic movements, stresses and strains on tubular/casings including twisting, shearing, compressions, expansion, buckling and any form of deformation; chemical or radioactive tracer detection; fluid identification such as gas detection; water detection, carbon dioxide detection, hydrate, wax and sand production; and fluid properties such as (but not limited to) flow, density, water cut, resistivity, pH, viscosity, bubble point, gas/oil ratio, hydrocarbon composition, fluid colour or fluorescence.
  • the sensors may be imaging, mapping and/or scanning devices such as, but not limited to, camera, video, infra-red, magnetic resonance, acoustic, ultrasound, electrical, optical, impedance and capacitance. Sensors may also monitor equipment in the well, for example valve position, or motor rotation. Furthermore the sensors may be adapted to induce the signal or parameter detected by the incorporation of suitable transmitters and mechanisms.
  • the apparatus especially the sensors may comprise a memory device which can store data for recovery at a later time.
  • the memory device may also, in certain circumstances, be retrieved and data recovered after retrieval.
  • the memory device may be configured to store information for at least one minute, optionally at least one hour, more optionally at least one week, preferably at least one month, more preferably at least one year or more than five years.

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Claims (20)

  1. Bohrloch-Datenkommunikationsvorrichtung zur Verwendung in einer Bohrungsanlage mit einer Metallstruktur (2), die mit einem Kathodenschutzsystem versehen ist, sodass ein die Metallstruktur (2) und eine Masserückleitung umfassender elektrischer Stromkreis vorliegt, in dem als Folge des Kathodenschutzsystems ein elektrischer Strom fließt, wobei die Bohrloch-Datenkommunikationsvorrichtung Folgendes umfasst:
    ein erstes Kommunikationsmodul zur Positionierung an einem ersten Ort (41a) im Bohrloch und umfassend Modulationsmittel zum Modulieren des elektrischen Stroms an einem ersten Ort (41a), um Daten zu verschlüsseln;
    ein zweites Kommunikationsmodul zur Positionierung an einem von dem ersten Ort (41a) beabstandeten zweiten Ort (41b), und umfassend einen Detektor zum Erfassen der Auswirkung der Modulation des elektrischen Stroms an dem ersten Ort (41a), um die Daten auszuziehen; und
    ein Modul zur Gewinnung von elektrischer Leistung im Bohrloch, das zur elektrischen Kopplung zwischen zwei beabstandeten Orten in einer Bohrungsanlage angeordnet ist, und umfassend einen elektrischen Stromkreis, der dazu angeordnet ist, im Gebrauch elektrische Energie aus einer Potentialdifferenz zwischen den zur Gewinnung genutzten beabstandeten Orten zu gewinnen, die als Eingangsspannung dient, wobei das Gewinnungsmodul dazu angeordnet ist, mindestens einer Komponente der Kommunikationsvorrichtung Leistung zuzuführen,
    wobei das erste Kommunikationsmodul dazu angeordnet ist, eine von dem Gewinnungsmodul erzeugte Last zu steuern, um die Modulation des elektrischen Stroms in der Metallstruktur (2) an dem Signalisierungsort zu bewirken.
  2. Bohrloch-Datenkommunikationsvorrichtung nach Anspruch 1, wobei das Modulationsmittel zu mindestens einem der Folgenden angeordnet ist:
    i) wenn es sich bei dem Kathodenschutzsystem um ein Fremdstrom-Kathodenschutzsystem handelt, Steuern einer Signalquelle des Fremdstrom-Kathodenschutzsystems dazu, den an die Metallstruktur (2) angelegten Kathodenschutzstrom direkt zu modulieren;
    ii) Abwandeln der Kopplung zwischen mindestens einer Anode des Kathodenschutzsystems und der Metallstruktur (2); und
    iii) Ändern der Impedanz des elektrischen Stromkreises.
  3. Bohrloch-Datenkommunikationsvorrichtung nach einem der vorangehenden Ansprüche, wobei das zweite Kommunikationsmodul zur Positionierung im Bohrloch angeordnet ist.
  4. Bohrloch-Datenkommunikationsvorrichtung nach einem der vorangehenden Ansprüche, umfassend ein Sensormodul zum Abfühlen mindestens eines Parameters, wobei das erste Kommunikationsmodul dazu angeordnet ist, Messwerte verschlüsselnde Daten von dem Sensormodul in Richtung des zweiten Kommunikationsmoduls zu senden.
  5. Bohrloch-Datenkommunikationsvorrichtung nach Anspruch 4, wobei das Sensormodul einen Drucksensor umfasst.
  6. Bohrloch-Datenkommunikationsvorrichtung nach einem der vorangehenden Ansprüche, wobei das zweite Kommunikationsmodul dazu angeordnet ist, Daten in Abhängigkeit von Daten, die das zweite Kommunikationsmodul von dem ersten Kommunikationsmodul her empfängt, einem Bohrlochgerät bereitzustellen.
  7. Bohrloch-Datenkommunikationsvorrichtung nach Anspruch 6, wobei das Bohrlochgerät mindestens eines der Folgenden umfasst:
    einen Bohrlochsensor;
    einen Bohrlochaktor;
    eine ringförmige Dichtungsvorrichtung, zum Beispiel eine Dichtpackung oder ein Dichtpackungselement;
    ein Ventil;
    ein Bohrlochkommunikationsmodul, zum Beispiel einen Transceiver oder einen Repeater.
  8. Bohrloch-Datenkommunikationsvorrichtung nach Anspruch 7, wobei das Ventil mindestens eines der Folgenden umfasst:
    ein unterirdisches Sicherheitsventil;
    ein Bohrungsströmungsregelventil;
    ein Ventil zwischen Bohrung und Ringspalt;
    ein Ventil zwischen Ringspalt und Ringspalt;
    ein Ventil zwischen Bohrung und Druckausgleichskammer;
    ein Ventil zwischen Ringspalt und Druckausgleichskammer;
    ein Ventil durch eine Packdichtung oder ein Packdichtungs-Umgehungsventil.
  9. Bohrloch-Datenkommunikationsvorrichtung nach einem der vorangehenden Ansprüche, wobei das erste und/oder das zweite Kommunikationsmodul einen Kommunikations-Repeater zur Positionierung im Bohrloch in einer Bohrung umfasst, der dazu angeordnet ist, unter Verwendung eines Kommunikationskanals, der mindestens durch den Bohrungskopf drahtlos ist und dazu angeordnet ist, mit einem in der Bohrung und somit unter dem Bohrungskopf positionierten zweiten Gerät zu kommunizieren, mit einem ersten Gerät hinter dem Bohrungskopf zu kommunizieren, sodass der Kommunikations-Repeater als Repeater zwischen dem ersten und dem zweiten Gerät wirken kann.
  10. Bohrloch-Datenkommunikationsvorrichtung nach einem der vorangehenden Ansprüche, wobei das Gewinnungsmodul dazu angeordnet ist, elektrische Energie aus Gleichströmen zu gewinnen.
  11. Bohrloch-Datenkommunikationssystem, umfassend eine Bohrloch-Datenkommunikationsvorrichtung nach einem der vorangehenden Ansprüche, die in einer Bohrungsanlage mit einer mit einem Kathodenschutz versehenen Metallstruktur (2) positioniert ist.
  12. Bohrloch-Datenkommunikationssystem nach Anspruch 11, wobei es sich bei der Bohrung um eine Unterseebohrung handelt.
  13. Bohrloch-Datenkommunikationssystem nach Anspruch 11 oder Anspruch 12, wobei die Vorrichtung ein Modul zur Gewinnung von elektrischer Leistung im Bohrloch umfasst, das zwischen zwei beabstandeten Orten in der Bohrungsanlage elektrisch gekoppelt ist und umfassend einen elektrischen Stromkreis der dazu angeordnet ist, im Gebrauch elektrische Energie aus einer Potentialdifferenz zwischen den zur Gewinnung genutzten beabstandeten Orten zu gewinnen, die als Eingangsspannung dient, wobei das Gewinnungsmodul dazu angeordnet ist, mindestens einer Komponente der Kommunikationsvorrichtung Leistung zuzuführen.
  14. Bohrloch-Datenkommunikationssystem nach Anspruch 13, wobei der Stromfluss in Abschnitten der Metallstruktur (2) in Gebieten zwischen den zur Gewinnung genutzten beabstandeten Orten in derselben Längsrichtung erfolgt.
  15. Bohrloch-Datenkommunikationssystem nach Anspruch 13 oder Anspruch 14, wobei ein ununterbrochener Stromfließweg zwischen den zur Gewinnung genutzten beabstandeten Orten vorliegt, der mindestens teilweise über die Metallstruktur (2) geht.
  16. Bohrloch-Datenkommunikationssystem nach einem der Ansprüche 11 bis 15, wobei das erste und/oder das zweite Kommunikationsmodul in einem eingeschlossenen Ringspalt der Bohrung positioniert ist.
  17. Bohrloch-Datenkommunikationssystem nach einem der Ansprüche 11 bis 16, umfassend einen Drucksensor, der dazu angeordnet ist, den Speicherdruck der Bohrung zu überwachen.
  18. Bohrloch-Datenkommunikationssystem nach einem der Ansprüche 11 bis 17, umfassend einen Drucksensor, der dazu angeordnet ist, den Druck in einem Ringspalt der Bohrung zu überwachen.
  19. Bohrloch-Datenkommunikationssystem nach einem der Ansprüche 11 bis 18, umfassend einen Drucksensor, der dazu angeordnet ist, den Druck in einem eingeschlossenen Ringspalt der Bohrung zu überwachen.
  20. Bohrloch-Bohrungsanlage, die Folgendes umfasst:
    eine Bohrloch-Metallstruktur (2), die mit einem Kathodenschutzsystem versehen ist, sodass ein die Metallstruktur (2) und eine Masserückleitung umfassender elektrischer Stromkreis vorliegt, in dem als Folge des Kathodenschutzsystems ein elektrischer Strom fließt, und eine Bohrloch-Datenkommunikationsvorrichtung nach Anspruch 1, wobei das erste Kommunikationsmodul im Bohrloch in der Bohrungsanlage bereitgestellt ist.
EP16829111.0A 2016-12-30 2016-12-30 Bohrlochkommunikation Active EP3563033B1 (de)

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CN114526064A (zh) * 2022-04-21 2022-05-24 西南石油大学 一种套管井井地信号双向无线电磁传输装置及方法

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