WO2017064472A1 - Procédé et système de localisation et de détermination d'orientation d'objet en fond de trou - Google Patents

Procédé et système de localisation et de détermination d'orientation d'objet en fond de trou Download PDF

Info

Publication number
WO2017064472A1
WO2017064472A1 PCT/GB2016/053094 GB2016053094W WO2017064472A1 WO 2017064472 A1 WO2017064472 A1 WO 2017064472A1 GB 2016053094 W GB2016053094 W GB 2016053094W WO 2017064472 A1 WO2017064472 A1 WO 2017064472A1
Authority
WO
WIPO (PCT)
Prior art keywords
orientation
acoustic
vibrational
downhole
perforating gun
Prior art date
Application number
PCT/GB2016/053094
Other languages
English (en)
Inventor
Craig Milne
Original Assignee
Silixa Ltd.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Silixa Ltd. filed Critical Silixa Ltd.
Publication of WO2017064472A1 publication Critical patent/WO2017064472A1/fr

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/11—Perforators; Permeators
    • E21B43/116—Gun or shaped-charge perforators
    • E21B43/117—Shaped-charge perforators
    • 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
    • E21B47/02—Determining slope or direction
    • E21B47/024—Determining slope or direction of devices in the borehole
    • 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
    • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
    • E21B47/017—Protecting measuring instruments
    • 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
    • E21B47/02—Determining slope or direction
    • E21B47/022—Determining slope or direction of the borehole, e.g. using geomagnetism
    • 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
    • E21B47/02—Determining slope or direction
    • E21B47/022—Determining slope or direction of the borehole, e.g. using geomagnetism
    • E21B47/0224—Determining slope or direction of the borehole, e.g. using geomagnetism using seismic or acoustic means
    • 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
    • E21B47/09—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
    • 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
    • E21B47/09—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
    • E21B47/092—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes by detecting magnetic anomalies
    • 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
    • E21B47/14—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 using acoustic waves
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
    • G01V1/44—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well

Definitions

  • the present invention provides a method and system for determining the orientation and/or location of a downhole object. Particular embodiments provide for a co-located device with a perforating gun that is able to determine its own orientation and communicate the determined orientation back to the surface.
  • DAS distributed acoustic sensing
  • a pulse of light is sent into the optical fibre, and a small amount of light is naturally back scattered, along the length of the fibre by Rayleigh, Brillouin and Raman scattering mechanisms.
  • the scattered light is captured by the fibre and carried back towards the source where the returning signal is measured against time, allowing measurements in the amplitude, frequency and phase of the scattered light to be determined.
  • the glass structure of the optical fibre is caused to contract and expand within the vibro-acoustic field, consequently varying the optical path lengths between the back scattered and/or reflected light scattered from different locations along the fibre
  • the returning signal can be processed in order to measure the acoustical and/or vibrational field(s) at all points along the structure.
  • DAS distributed acoustic sensing systems
  • standard fibre optic cables are utilised to obtain a measurement profile from along the entire length of the fibre at intervals ranging from 1-10 metres.
  • DAS distributed acoustic sensing systems
  • iDASTM available from Silixa Limited, of Elstree, UK
  • WO2010/0136809 Systems such as these are able to digitally record acoustic fields at every interval location along an optical fibre at frequencies up to 100kHz. Since the location of the acoustic sensors is known (the fibre deployment being known), the position of any acoustic signal can be thus identified by means of time-of-arrival calculations.
  • DAS systems find lots of applications in the oil and gas industry, and optical fibers that can be connected to DAS systems, amongst other things, are often installed within wellbores, usually as a metal cable running parallel with the well bore casing clamped to the outside thereof.
  • cement is used to fill the well bore external of the casing.
  • the casing and cement is perforated within the hydrocarbon bearing regions, to allow hydrocarbons to flow into the casing for extraction. Perforation is typically performed by a perforating gun, which is typically a cylindrical metal tube provided with shaped explosive charges arranged around the circumference thereof.
  • the perforating gun is lowered through the casing to the intended production zone, and the shaped charges are detonated, with the intention of blasting holes through the casing and cement of the well, and into the surrounding rock strata, to allow hydrocarbons to then flow through the created channels into the casing for extraction.
  • the created holes provide routes for the fracturing fluid to exit the well into the surrounding rock.
  • FIG 11 illustrates the use of a perforating gun to generate perforations in a well bore casing and cement, and into the surrounding rock strata.
  • Perforating gun 10 comprises a metal cylinder provided with shaped explosive charges arranged around the outer surface thereof.
  • the shaped charges may be provided in lines every 120 degrees around the outer circumference of the gun.
  • the gun is provided with a communications line 12 to the surface for control purposes, to allow the explosive charges to be detonated on command.
  • the gun is lowered to the intended production zone, and the shaped charges detonated to blast through the casing and cement (as shown in Figure 11(b)), to create production channels in the surrounding rock strata through which oil or gas can flow to enter the well bore (as shown in Figure 11 (c)) .
  • perforating guns try and prevent the shaped charges from damaging any control or sensing cabling or other lines that may extend along the wellbore external of the casing.
  • optical fibers are commonly installed along the external surface of the casing within the wellbore, either for sensing purposes and/or for control of downhole tools. Care must be taken when using a perforating gun that the shaped charges are not pointed at the external cabling or other lines such that the charges when detonated would sever such lines.
  • the perforating is performed as part of the well completion, by that point the fibers have typically already been cemented into the well bore, and hence repair can be very costly, or even impossible.
  • the fibers and other signalling lines are located between two metal rods or cables, and a magnetometer is provided on the perforating gun to try and detect the metal rods. That is, the rotational orientation of the perforating gun is altered within the casing whilst the magnetometer is used to detect the location of the metal rods either side of the fibers or other cabling. Once the metal rods have been detected, the orientation of the perforating gun can be controlled to ensure that the shaped charges are pointed away from the area of the metal rods, and hence the cabling or other lines to be protected.
  • the metal rods are usually required to extend along a significant length of the well bore, hence increasing the material and production cost of the well.
  • the use of magnetometers to detect the rods is not particularly accurate, and particularly in some rock formations or in some regions where magnetic anomalies can occur that interfere with the operation of the magnetometers.
  • the presence of the casing and other downhole equipment can interfere with the proper operation of the magnetometers, meaning that it is not reliably possible to rotationally orient the perforating gun within the casing to ensure that the sensor and control lines and/or other cabling will not be damaged by the use of the perforating gun.
  • the rods also form a potential leakage path up the outside of the casing.
  • WO2013/030555 describes a method and apparatus for determining the relative orientation of objects downhole, and especially to determining perforator orientation.
  • the method involves varying the orientation of an object, such as a perforator gun (302) in the wellbore and activating at least one directional acoustic source (402a-c).
  • Each directional acoustic source is fixed in a predetermined location to the object and transmits an acoustic signal preferentially in a known direction.
  • the directional acoustic source(s) is/are activated so as to generate sound in a plurality of different orientations of said object.
  • An optical fiber (104) deployed down the wellbore is interrogated to provide distributed acoustic sensing in the vicinity of the object and the acoustic signals detected by the optical fiber are analyzed so as to determine the orientation of the at least one directional acoustic source relative to the optical fiber, for instance by looking at the relative intensity in the different orientations. Further details of the operation of the arrangement are described in the document, any and all of which necessary for understanding the present invention being incorporated herein by reference.
  • the arrangement in WO2013/030555 apparently should overcome the cost and inaccuracy of the prior art magnetometer arrangements, the arrangement relies on the operation of a DAS system to detect the directional acoustic sources, with the directional acoustic sources being described as conventional loudspeakers arranged to project sounds forward and located in a casing that absorbs sound emitted in other directions.
  • Conventional loudspeakers typically operate within audible frequency bands, for example in the range 20 Hz to 20kHz, and a typical DAS of the prior art is usually capable of detecting sound at these frequencies with good spatial resolution.
  • Embodiments of the invention provide a downhole device that is intended to be co-located with a perforating gun, or another part such as orientation weights attached to a perforating gun
  • the device has an accelerometer or other suitable orientation determining means that is able to determine its positional orientation, with respect to gravity.
  • a vibrator or other sounder is provided, that outputs the positional orientation information as a suitably encoded and modulated acoustic signal.
  • a fiber optic distributed acoustic sensor deployed in the vicinity of the downhole device detects the acoustic signal and transmits it back to the surface, where it is demodulated and decoded to obtain the positional orientation information. Given that the device is co-located with the perforating gun the position of the gun can then be inferred. As explained above, detecting the gun position with respect to any optical fibers running along the well is important during perforation operations, so that the fiber is not inadvertently damaged.
  • Also described herein is the more general concept of having remote sensing devices deployed in an environment to be sensed and that sense local conditions and/or stimuli with appropriate sensors, and that then produce modulated vibro- acoustic signals encoding the sensed local conditions and/or stimuli.
  • the vibro- acoustic signals are then detected by the optical fiber of an optical fiber distributed acoustic sensor system, the fiber being deployed into the environment to be sensed.
  • the incident vibro-acoustic signals on the fiber in turn modulate backscatter and/or reflected optical signals that propagate back along the fiber, and which are then detected at a DAS processing box to which the fiber is connected to allow the vibro acoustic signals to be sensed.
  • an apparatus comprising: i) an orientation detector arranged to detect the orientation of the apparatus; and ii) a vibrational or acoustic source arranged to produce vibrational or acoustic signals in dependence on the detected orientation of the apparatus, the produced vibrational or acoustic signals representing the detected orientation.
  • the apparatus may be mounted on a carrier forming part of or attached to a perforating gun, in such a manner that determination of orientation of the apparatus also provides information as to the orientation of the perforating gun.
  • an apparatus may be used downhole to determine orientation of downhole elements, such as a perforating gun, or weights attached to a perforating gun.
  • the orientation detector is a relative bearing sensor based on a magnetic encoder with eccentric weight sensitive to gravity when placed off the vertical plane.
  • the relative bearing sensor detects the orientation of the apparatus with respect to the direction of gravity.
  • the orientation detector is a three-axis accelerometer that preferably detects the orientation of the apparatus with respect to gravity.
  • the orientation detector comprises one or more offset rotatably mounted magnetic masses, and a magnetic detector arranged to detect the rotational orientation of the offset magnetic masses.
  • the orientation detector may be a relative bearing sensor.
  • the vibrational or acoustic source is arranged to generate a modulated vibrational or acoustic signal that encodes information pertaining to the detected orientation. In this way, information can be transmitted vibro- acoustically from the downhole device.
  • the vibrational or acoustic signal is frequency modulated whereby to encode the information pertaining to the detected orientation.
  • frequency modulated signals are easier for a DAS detector to discriminate.
  • the frequency modulation comprises selection of one or a set of predetermined modulation frequencies corresponding to respective predetermined orientations.
  • the set of predetermined modulation frequencies may be selected such that no member of the set is a harmonic frequency of any other member of the set. In this way, discrimination between frequencies and accurate communication of information is established.
  • the vibrational or acoustic source is an impulse source that generates vibrational or acoustic impulses at one or more frequencies corresponding to respective one or more detected orientations. Again, such a signal is relatively easy for a DAS to detect and discriminate.
  • the impulse source is an electro-mechanical tapper, such as for example, a solenoid driven device, or a piezo-electric driven device. As a consequence, tapping signals of controllable frequency that are easy for the DAS to detect can be generated.
  • the apparatus is provided within a sealed case within which the orientation detector and the vibrational and/or acoustic source are contained. Such an arrangement helps to protect the apparatus from environmental conditions encountered downhole.
  • the apparatus further includes initiation circuitry, arranged to detect an external initiation condition that indicates that the orientation detector and vibrational and/or acoustic source should begin to operate, the apparatus remaining quiescent until such condition is detected.
  • initiation circuitry arranged to detect an external initiation condition that indicates that the orientation detector and vibrational and/or acoustic source should begin to operate, the apparatus remaining quiescent until such condition is detected.
  • the external initiation condition is one or more of: i) a magnetic field of at least a predefined activation value; ii)an electronic time delay of predetermined duration; iii) an acceleration or shock of at least a minimum predefined activation value; or iv) a temperature of at least a minimum predefined activation value; wherein the predefined activation values are greater than typical ambient values.
  • the downhole device can also receive vibro-acoustic signals and so that it can be activated and operated remotely.
  • the downhole device can be turned on, send back the information and then go back to a standby condition with a low power requirement. This can extend the operating life of the device.
  • Another aspect of the invention provides a distributed acoustic sensor system, comprising an optical fiber deployed along a well bore and a signal processing apparatus arranged to receive optical backscatter and/or reflections from along the optical fiber and to process such backscatter and/or reflections to determine vibrational and/or acoustic signals incident on the optical fiber, vibrational or acoustic signals from an apparatus according to the first aspect above being detected by said distributed acoustic sensor system and processed to thereby determine the orientation of the apparatus.
  • a system comprising: i) a downhole or remote device, provided with at least one vibrational transducer and arranged to listen for vibro- acoustic or seismic signals pertaining to the downhole or remote device, and to produce vibro-acoustic signals pertaining to the downhole or remote device; ii) a fiber optic distributed acoustic sensor system, comprising an optical fiber deployed downhole or into a sensing environment from a local position and arranged to listen for the vibro-acoustic signals produced by the downhole or remote device; and iii) a transducer arranged to transmit vibro-acoustic or seismic signals into the ground or into the sensing environment; wherein the fiber optic distributed acoustic sensor system communicates information from the downhole device to the surface by listening for the vibro-acoustic signals produced by the downhole device, and the transducer communicates information to the downhole or remote device.
  • the downhole device may also be equipped with one or more further sensors, such as a pressure sensor, temperature sensor, chemical sensor, or gravity, to measure properties of its surroundings along the well bore or in the reservoir. The measurements may then be communicated by a suitably encoded vibro-acoustic signal output by a vibro-acoustic transducer on the device, such as a speaker or other sounder.
  • a vibro-acoustic transducer on the device, such as a speaker or other sounder.
  • An array processing of the distributed acoustic data may be used to improve the localisation of the device as well as improving the vibro-acoustic sensitivity.
  • the embodiment may also be applied for remote sensing and communications for inland as well as for subsea.
  • the optical fiber DAS may be used as a return communications channel for any remote sensing devices deployed within a sensing environment, which need not be a subterranean environment, but can be any environment into which an optical fiber can be deployed, and which supports the propagation of vibro-acoustic energy.
  • the remote sensing devices sense local conditions and/or stimulil within their local part of the sensing environment, and then generate a vibro- acoustic signal encoding the sensed local conditions and/or stimuli.
  • the vibro- acoustic signal is then detected by the optical fiber of the DAS, which communicates it back to the locality of the DAS processor.
  • the optical fiber DAS acts as a communications channel to communicate sensor information from the remote devices back out of the sensing environment.
  • a forward channel may also be provided, to allow communications with the remote devices. If the remote devices are deployed underground, this forward channel might for example use a seismic transducer or other vibrational device to generate modulated vibrations to be transmit through the ground to the devices. Where the devices are above ground, appropriate radio channels may be used. Where the devices are subsea, acoustic based channels, such as sonar type channels, may be used.
  • Figure 1 is a diagram illustrating tubing having a fiber on the outside thereof held in place by clamps;
  • Figure 2 is a cross-section of part of Figure 1;
  • FIG. 3 is a block diagram of the components of an apparatus according to an embodiment of the invention.
  • Figure 4 is a cross section of a part of Figure 1;
  • Figure 5 is the cross section of Figures 2 and 4, annotated to show orientation detection
  • Figure 6 is a diagram illustrating the operation of an embodiment of the invention.
  • Figure 7 is an illustration of a clamp used in an embodiment of the invention
  • Figure 8 is flow diagram of a first process used in an embodiment of the invention
  • Figure 9 is flow diagram of a second process used in an embodiment of the invention.
  • Figure 10 is flow diagram of a third process used in an embodiment of the invention.
  • FIGS 11 and 12 are diagrams of aspects of the prior art
  • Figure 13 is a block diagram of components of an apparatus according to a second embodiment of the invention.
  • Figure 14 is a cross -section of the apparatus of .of Figure 13;
  • Figure 15 is an illustration of a clamp used in the second embodiment of the invention;
  • Figure 16 is a flow diagram of a process used in the second embodiment of the invention.
  • Figure 17 is diagram of a further embodiment of the invention.
  • Figure 18 is a diagram of the internal components of the embodiment of Figure 17;
  • Figure 19 is a diagram of a solenoid used in the embodiment of Figure 17;
  • Figure 20 is a diagram of some of the internal components of the embodiments of Figure 17;
  • Figure 21 is a block diagram illustrating a further mode of operation of embodiments of the invention.
  • Figure 22 is a diagram illustrating a typical perforating gun, with eccentric weights to passively align the gun in a desired firing direction
  • a DAS system (such as the Silixa ® iDASTM) detects the individual signals from each tool and dedicated software decodes and plots the measurement to indicate the relative rotational direction of the tool, and hence the perforating gun to which it is affixed.
  • the relative bearing may typically refer to the angle relative to the high side of the hole.
  • a DOT device may also have batteries and charging circuitry to allow for that inductive charging.
  • a hybrid fiber optic/electric cable may be installed in place of the fiber optic cable, which interacts with the charging circuitry to inductively charge the batteries.
  • the DAS system may be a Silixa ® iDASTM system, the details of operation of which are available at the URL http://www.si]ixax'OT.n/technologv/ida.8/, and which is also described in our earlier patent application WO2010/0136809, any details of which that are necessary for understanding the present invention being incorporated herein by reference.
  • Figure 13 shows a section along the line B-B of Figure 14.
  • the downhole orientation tool device 122 comprises an outer casing, within which is contained a relative bearing sensor 132, which is arranged to communicate with an electronics package 134.
  • the electronics package 134 receives signals from the relative bearing sensor, and determines the orientation of the downhole orientation tool with respect to gravity, in a manner to be described. Having determined the orientation with respect to gravity, the electronics package 134 then controls a vibrator 36, to vibrate in a specific pattern in order to communicate the determined orientation. That is, the vibrator 36 produces a modulated vibro-acoustic signal that encodes the determined orientation, as determined by the electronics package.
  • the components of the downhole orientation tool 122 are powered by a battery 38.
  • a 2- way communication can also be created which can be done by an acoustic or seismic source (212) at the surface, near the surface or sub-surface, with the DAS then being used to also confirm that the signal has been communicated/ received to the point of interest i.e. at the downhole device.
  • an acoustic or seismic source 212
  • the DAS then being used to also confirm that the signal has been communicated/ received to the point of interest i.e. at the downhole device.
  • Figure 21 illustrates such an arrangement.
  • casing 10 is provided with an optical fiber held in place by clamps 12.
  • DAS system 62 interrogates the optical fiber by sending optical pulses therealong and detecting the backscatter and/or reflections that come back from the pulses as they travel along the fiber. From the back scatter and/or reflections, which are modulated along the fiber by incident vibro-acoustic energy, the acoustic field at each location along the fiber can be determined.
  • an acoustic or seismic source 212 is provided at or near the surface, or under the surface, which is used to generate acoustic or seismic signals, the information content of which can be modulated to convey desired control signals to the remote DOT devices.
  • Remote sensing devices which may be in the same form as the DOT devices described herein, or may take other forms, but which can send data vibro- acoustically are further provided. Localisation of such devices can be undertaken using array processing techniques, for example based on the distributed acoustic data from the DAS system 62. Deployment of the remote sensing devices 214 can be undertaken by them being pumped or injected or deployed on the surface, subsurface and/or subsea.
  • cylindrical tube 172 is shown as cylindrical tube 172 in Figure 17.
  • cylindrical tube 172 is formed from stainless steel, and is provided at both ends with respective caps 174, also made from stainless steel.
  • the caps 174 are respectively laser welded all the way around their circumferences to secure them to the stainless tube with a fluid tight seal.
  • Figure 18 shows the interior of the stainless steel tube 172.
  • the components are arranged in a cylindrically stacked configuration so as to allow them to be fitted inside the stainless steel tube 172.
  • the DOT according to this embodiment comprises a solenoid housing 182, within which is included a solenoid or other electromechanical actuator that is able to produce a mechanical movement in response to the application of an electrical signal.
  • a solenoid housing 182 within which is included a solenoid or other electromechanical actuator that is able to produce a mechanical movement in response to the application of an electrical signal.
  • other suitable actuators may be high temperature piezo-electric actuators, or the like.
  • the solenoid body is of standard construction as is known in the art, having a metal plunger extending through the centre of the solenoid body. Inside the solenoid body are a plurality of turns of wire, as is known in the art.
  • the plunger is provided at one end with a cap providing a shoulder for a spring that is arranged coaxially with the plunger therearound, and which abuts against the shoulder and the solenoid body to provide a spring return of the plunger to its rest position once it has been moved by the solenoid coil.
  • the second PCB 206 has mounted thereon a microcontroller, arranged to interface with a brass magnet holder 214 that forms part of a magnetic sensor, arranged to detect the rotational position of two offset magnetic weights 212 mounted on a shaft.
  • the weights 212 are arranged offset to the shaft such that shaft extends off-center through the weights, whereby the off-center weights rotate about the shaft in an eccentric manner.
  • the shaft is held in place by a bearing 210, which is fixed in place with respect to the spinner housing by a bearing housing 208, mounted on the spinner housing 186.
  • the DOT transmits a signal representing the detected angular orientation as a pulsing of the solenoid 192.
  • the angle is encoded as the pulsing frequency.
  • the apparatus is sealed at manufacture (so that no interaction is needed at the well site) and comes alive in the following manner: a. After being installed downhole the ambient temperature is increased, and at the predetermined activation temperature the electronics is activated using the thermal switch 204. This means that the device draws no power until this condition is met, allowing the device to be sealed at manufacture many months before deployment. b. After activation the device then draws minimal power until no motion has been detected from the sensor for a predetermined period (for example around 4 hours) which should belong enough that the user knows the casing has "landed" i.e. settled into position. c. After this time period the solenoid turns on (i.e.
  • the frequencies are a set of quantised (digital) values rather than continuous (analogue) values. This prevents the harmonic issue described above, but in addition this pre-knowledge of what the possible set of frequencies helps to pick confidently the correct frequency/angle in the signal detection/processing stage. For example, similar processing to that used in a lock- in amplifier can be used to better identify the actual frequency from the limited number of possible frequencies.
  • Another ("out of band”) frequency is used (say 0.5Hz) for "no angle detected" - i.e. a fault c.
  • non-chemical (i.e. not battery) energy storage mechanisms may be provided to power the DOT.
  • a wind-up micro generator may be provided that starts unwinding at a set temperature.
  • a compressed air powered generator may be provided, which uses compressed air to power a micro-generator. In both cases, the time we could power the sound source may be very limited, but provided the signal is detected soon after actuation this is of little concern, as once installed the position will not change.
  • a balance wheel type clockwork powered mechanism may be provided where the regulator lever on the balance spring is linked to the offset weights such that rotation of the offset weights adjusts the regulator lever so as to alter the oscillation of the balance wheel, and hence the resultant tapping frequency generated via a tapping mechanism driven by the balance wheel oscillation.
  • inductive charging of the DOT batteries may be possible, for example where there is a hybrid electric/fiber optic cable and inductive charging circuitry is included, as discussed previously.
  • FIGs 22 and 23 illustrate a further embodiment, showing another use for the DOT devices described above, to determine orientation of a perforating gun 222 itself.
  • Passively oriented perforation guns 222 are positioned in deviated wells using eccentric weights 221 as shown in Figure 22. These weights 221 find the low side of the well by gravity provided that there is sufficient deviation and that there is no obstruction.
  • Perforating guns 222 are connected to the eccentric weights 221 such that the charges point to the desired angle when the weights are lying on the low side of the hole. In the example of Figure 22 the charges are pointed with a relative bearing of 270° relative to the high side when looking downhole.
  • a DOT device (22, 122, 172) identical to any of the previously described arrangements is installed on the topside of the eccentric weight bars 221 so that the index (etching) is pointed towards the top of the deviated hole.
  • the DOT will read 180° according to the primary usage of fiber optic cable mapping described previously, and hence in this embodiment the DOT device can be reprogrammed to measure 0° in this mode.

Landscapes

  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Geophysics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Acoustics & Sound (AREA)
  • Remote Sensing (AREA)
  • General Physics & Mathematics (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Measurement Of Mechanical Vibrations Or Ultrasonic Waves (AREA)

Abstract

Selon certains modes de réalisation, cette invention concerne un dispositif de fond de trou qui est conçu pour être positionné conjointement avec un train de perforateur, de sorte à permettre de déterminer l'orientation en rotation de celui-ci lorsqu'il est déployé en fond de trou. Ledit dispositif possède un accéléromètre ou d'autres moyens appropriés de détermination d'orientation, aptes à déterminer son orientation de position, en fonction de la pesanteur. Un vibreur ou un autre sondeur est fourni, lequel délivre en sortie les informations d'orientation de position sous la forme d'un signal acoustique approprié, codé et modulé. Un capteur acoustique réparti à fibres optiques déployé dans le voisinage du dispositif de fond de trou détecte le signal acoustique, et le transmet en retour vers la surface, où il est démodulé et décodé pour obtenir les informations d'orientation de position. Étant donné que le dispositif est positionné conjointement avec le perforateur, la position du perforateur peut ensuite être déduite.
PCT/GB2016/053094 2015-10-12 2016-10-05 Procédé et système de localisation et de détermination d'orientation d'objet en fond de trou WO2017064472A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB1518026.8A GB2546061B (en) 2015-10-12 2015-10-12 Method and system for downhole object location and orientation determination
GB1518026.8 2015-10-12

Publications (1)

Publication Number Publication Date
WO2017064472A1 true WO2017064472A1 (fr) 2017-04-20

Family

ID=55130926

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2016/053094 WO2017064472A1 (fr) 2015-10-12 2016-10-05 Procédé et système de localisation et de détermination d'orientation d'objet en fond de trou

Country Status (2)

Country Link
GB (1) GB2546061B (fr)
WO (1) WO2017064472A1 (fr)

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN107060715A (zh) * 2017-05-19 2017-08-18 中国石油集团川庆钻探工程有限公司 用于压裂酸化改造的井下定向水力喷射工具
CN107227948A (zh) * 2017-05-19 2017-10-03 中国石油集团川庆钻探工程有限公司 地面控制井下定向水力喷射工具的方法
FR3097587A1 (fr) * 2019-06-21 2020-12-25 Febus Optics Dispositif de maintenance et procede pour determiner la position d’un point de blocage d’un element tubulaire
US10975687B2 (en) 2017-03-31 2021-04-13 Bp Exploration Operating Company Limited Well and overburden monitoring using distributed acoustic sensors
US11053791B2 (en) 2016-04-07 2021-07-06 Bp Exploration Operating Company Limited Detecting downhole sand ingress locations
JP2021111823A (ja) * 2020-01-07 2021-08-02 国立大学法人信州大学 情報伝送装置および移動体および情報伝送方法および情報伝送プログラム
US11098576B2 (en) 2019-10-17 2021-08-24 Lytt Limited Inflow detection using DTS features
US11162353B2 (en) 2019-11-15 2021-11-02 Lytt Limited Systems and methods for draw down improvements across wellbores
US11199085B2 (en) 2017-08-23 2021-12-14 Bp Exploration Operating Company Limited Detecting downhole sand ingress locations
US11199084B2 (en) 2016-04-07 2021-12-14 Bp Exploration Operating Company Limited Detecting downhole events using acoustic frequency domain features
CN113898322A (zh) * 2021-11-16 2022-01-07 成都百胜野牛科技有限公司 天然气井流体分隔器
US11333636B2 (en) 2017-10-11 2022-05-17 Bp Exploration Operating Company Limited Detecting events using acoustic frequency domain features
US11466563B2 (en) 2020-06-11 2022-10-11 Lytt Limited Systems and methods for subterranean fluid flow characterization
US11473424B2 (en) 2019-10-17 2022-10-18 Lytt Limited Fluid inflow characterization using hybrid DAS/DTS measurements
US11593683B2 (en) 2020-06-18 2023-02-28 Lytt Limited Event model training using in situ data
US11643923B2 (en) 2018-12-13 2023-05-09 Bp Exploration Operating Company Limited Distributed acoustic sensing autocalibration
US11859488B2 (en) 2018-11-29 2024-01-02 Bp Exploration Operating Company Limited DAS data processing to identify fluid inflow locations and fluid type

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11293271B1 (en) 2020-10-28 2022-04-05 Halliburton Energy Services, Inc. Low-profile adjustable fastener for charge orientation of a downhole perforating tool

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013030555A2 (fr) * 2011-08-26 2013-03-07 Optasense Holdings Limited Détermination d'orientation de perforation
WO2013039480A1 (fr) * 2011-09-13 2013-03-21 Halliburton Energy Services, Inc. Commande automatisée de vanne d'aiguillage pour opérations d'évacuation
WO2015047262A1 (fr) * 2013-09-26 2015-04-02 Halliburton Energy Services, Inc. Bouchon de cimentation permettant de déterminer l'orientation d'une colonne de tubage dans un puits de forage
GB2522654A (en) * 2014-01-31 2015-08-05 Silixa Ltd Method and system for determining downhole object orientation
GB2522741A (en) * 2014-01-31 2015-08-05 Silixa Ltd Method and system for determining downhole optical fiber orientation and/or location
WO2015173592A1 (fr) * 2014-05-16 2015-11-19 Silixa Ltd. Procédé et système de détermination de la localisation et l'orientation d'objet de fond de trou

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100133004A1 (en) * 2008-12-03 2010-06-03 Halliburton Energy Services, Inc. System and Method for Verifying Perforating Gun Status Prior to Perforating a Wellbore
GB0905986D0 (en) * 2009-04-07 2009-05-20 Qinetiq Ltd Remote sensing
US8584519B2 (en) * 2010-07-19 2013-11-19 Halliburton Energy Services, Inc. Communication through an enclosure of a line

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013030555A2 (fr) * 2011-08-26 2013-03-07 Optasense Holdings Limited Détermination d'orientation de perforation
WO2013039480A1 (fr) * 2011-09-13 2013-03-21 Halliburton Energy Services, Inc. Commande automatisée de vanne d'aiguillage pour opérations d'évacuation
WO2015047262A1 (fr) * 2013-09-26 2015-04-02 Halliburton Energy Services, Inc. Bouchon de cimentation permettant de déterminer l'orientation d'une colonne de tubage dans un puits de forage
GB2522654A (en) * 2014-01-31 2015-08-05 Silixa Ltd Method and system for determining downhole object orientation
GB2522741A (en) * 2014-01-31 2015-08-05 Silixa Ltd Method and system for determining downhole optical fiber orientation and/or location
WO2015173592A1 (fr) * 2014-05-16 2015-11-19 Silixa Ltd. Procédé et système de détermination de la localisation et l'orientation d'objet de fond de trou

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11053791B2 (en) 2016-04-07 2021-07-06 Bp Exploration Operating Company Limited Detecting downhole sand ingress locations
US11215049B2 (en) 2016-04-07 2022-01-04 Bp Exploration Operating Company Limited Detecting downhole events using acoustic frequency domain features
US11199084B2 (en) 2016-04-07 2021-12-14 Bp Exploration Operating Company Limited Detecting downhole events using acoustic frequency domain features
US11530606B2 (en) 2016-04-07 2022-12-20 Bp Exploration Operating Company Limited Detecting downhole sand ingress locations
US10975687B2 (en) 2017-03-31 2021-04-13 Bp Exploration Operating Company Limited Well and overburden monitoring using distributed acoustic sensors
CN107227948A (zh) * 2017-05-19 2017-10-03 中国石油集团川庆钻探工程有限公司 地面控制井下定向水力喷射工具的方法
CN107060715A (zh) * 2017-05-19 2017-08-18 中国石油集团川庆钻探工程有限公司 用于压裂酸化改造的井下定向水力喷射工具
US11199085B2 (en) 2017-08-23 2021-12-14 Bp Exploration Operating Company Limited Detecting downhole sand ingress locations
US11333636B2 (en) 2017-10-11 2022-05-17 Bp Exploration Operating Company Limited Detecting events using acoustic frequency domain features
US11859488B2 (en) 2018-11-29 2024-01-02 Bp Exploration Operating Company Limited DAS data processing to identify fluid inflow locations and fluid type
US11643923B2 (en) 2018-12-13 2023-05-09 Bp Exploration Operating Company Limited Distributed acoustic sensing autocalibration
US11384634B2 (en) 2019-06-21 2022-07-12 Febus Optics Maintenance device and method for determining the position of a blockage point of a tubular member
FR3097587A1 (fr) * 2019-06-21 2020-12-25 Febus Optics Dispositif de maintenance et procede pour determiner la position d’un point de blocage d’un element tubulaire
US11473424B2 (en) 2019-10-17 2022-10-18 Lytt Limited Fluid inflow characterization using hybrid DAS/DTS measurements
US11098576B2 (en) 2019-10-17 2021-08-24 Lytt Limited Inflow detection using DTS features
US11162353B2 (en) 2019-11-15 2021-11-02 Lytt Limited Systems and methods for draw down improvements across wellbores
JP7315924B2 (ja) 2020-01-07 2023-07-27 国立大学法人信州大学 情報伝送装置および移動体および情報伝送方法および情報伝送プログラム
JP2021111823A (ja) * 2020-01-07 2021-08-02 国立大学法人信州大学 情報伝送装置および移動体および情報伝送方法および情報伝送プログラム
US11466563B2 (en) 2020-06-11 2022-10-11 Lytt Limited Systems and methods for subterranean fluid flow characterization
US11593683B2 (en) 2020-06-18 2023-02-28 Lytt Limited Event model training using in situ data
CN113898322A (zh) * 2021-11-16 2022-01-07 成都百胜野牛科技有限公司 天然气井流体分隔器

Also Published As

Publication number Publication date
GB2546061B (en) 2021-10-13
GB201518026D0 (en) 2015-11-25
GB2546061A (en) 2017-07-12

Similar Documents

Publication Publication Date Title
AU2020204228B2 (en) Method and system for downhole object location and orientation determination
WO2017064472A1 (fr) Procédé et système de localisation et de détermination d'orientation d'objet en fond de trou
EP2748424B1 (fr) Détermination d'orientation de perforation
US10370954B2 (en) Method for surveying drill holes, drilling arrangement, and borehole survey assembly
US10119390B2 (en) Remote tool position and tool status indication
US20220364461A1 (en) Information Transfer System
JPS62142291A (ja) 音響検層装置
AU2015384170A1 (en) System and method for communicating along a casing string including a high magnetic permeability substrate

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 16781165

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 16781165

Country of ref document: EP

Kind code of ref document: A1