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EP0033192A1 - System zur akustischen Datenweiterleitung entlang einem Bohrloch-Gestängestrang - Google Patents

System zur akustischen Datenweiterleitung entlang einem Bohrloch-Gestängestrang Download PDF

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Publication number
EP0033192A1
EP0033192A1 EP19810300068 EP81300068A EP0033192A1 EP 0033192 A1 EP0033192 A1 EP 0033192A1 EP 19810300068 EP19810300068 EP 19810300068 EP 81300068 A EP81300068 A EP 81300068A EP 0033192 A1 EP0033192 A1 EP 0033192A1
Authority
EP
European Patent Office
Prior art keywords
piezoelectric transmitter
mass
spring
responsive
bore
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
EP19810300068
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English (en)
French (fr)
Inventor
Anthony Peter Nardi
William Harold Kent
Peter Graham Mitchell
Gary Jay Chanson
Alexander Murray Nicholson
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Sperry Corp
Original Assignee
Sperry Corp
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
Priority claimed from US06/114,040 external-priority patent/US4282588A/en
Priority claimed from US06/114,038 external-priority patent/US4283780A/en
Priority claimed from US06/114,039 external-priority patent/US4302826A/en
Application filed by Sperry Corp filed Critical Sperry Corp
Publication of EP0033192A1 publication Critical patent/EP0033192A1/de
Ceased legal-status Critical Current

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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
    • 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
    • E21B47/16—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 through the drill string or casing, e.g. by torsional acoustic waves

Definitions

  • the invention is particularly suited for use with well drilling equipment and is therefore illustrated herein in such an environment, it has application also in permanent down-well installations, such as in oil or water pumping equipment. In particular, it also has application in the telemetering of data to the earth's surface relative to the performance of a down-well pumping system for extracting energy from hot geothermal brine disposed in subterranean strata of the earth.. For example, it finds use in the acoustic data transmitting channel of geothermal systems such as are taught in the aforementioned U.S. Patent Nos. 3,988,896 and 4,107,987.
  • acoustic transmitter that is mechanically coupled to the drill string itself, as at sub-unit 37 of Figure 1.
  • Operation of the electrically excitable transmitter generates acoustic waves that propagate upwards in the drill string to the surface-located receiver.
  • Acoustic loss measurements made upon the types of pipes used in well drilling and in geothermal brine pumping systems clearly indicate that the sonic carrier must have a relatively low audio carrier frequency. The relatively low frequencies are required since higher frequencies suffer serious attenuation per unit length of piping of the aforementioned kind and acoustic propagation becomes difficult even at moderate well depths.
  • a further difficulty lies in the presence in the mechanical structure of the acoustic wave propagating piping of a plurality of sharp resonances whose locations and separations are often difficult to predetermine or to locate empirically in a complex mechanical structure.
  • curve 255 of Figure 9 shows the experimentally derived amplitude transmission characteristics of a length of drill string pipe between 2280 and 2340 Hz; it demonstrated a resonance peak about 2310 H z.
  • Curve 256 of Figure 9 shows the corresponding phase characteristic of the pipe sample. It is observed that the pass band width is only about 4 Hz at the 3dB points, and that there is a rapid phase shift at resonance.
  • the present invention can be used to provide a feedback system which allows the carrier frequency to adjust slightly within a closed loop, but causing it always to be close to the peak of the transmission resonance curve despite the adverse effects of changes in temperature, acoustic coupling, and the like.
  • This invention relates to systems for the acoustic propagation of data along bore-hole drilling strings. More particularly, the invention concerns such systems affording improved operation in the relatively low loss acoustic frequency propagation range of the drilling strings
  • the acoustic systems generally operate in relatively high frequency ranges spaced apart from the large volume of low frequency energy developed by the operating elements of the drilling process. Most of the drilling noise is concentrated in the relatively low frequency range which is desirable for acoustic telemetering because of its relatively low propagation loss characteristics. It is the object of the present invention efficiently to couple acoustic energy into the drill string at relatively high levels competitive with the level of the drilling noise.
  • a system for the acoustic propagation of data along a bore-hole drilling string having a longitudinal axis comprising piezoelectric transmitter means adapted for compression and elongation along a sensitive axis substantially parallel to the longitudinal axis when subjected to a variable electric field representative of the data to be propagated, spring means having one end thereof connected to the piezoelectric transmitter means, and mass means connected to the other end of the spring means.
  • the present invention provides, in one preferred form to be described, an acoustic communication system including an acoustic transmitter and receiver, wherein lower frequency acoustic waves, propagating in relatively loss free manner in well drilling string piping, are efficiently coupled to the drill string and propagate at levels competitive with the levels of drilling machinery generated noise energy also present in the drill string.
  • the transmitting transducer permits resonant operation in the desired lower frequency range.
  • the combination features a spring in the general shape of a bellow having spaced corrugations to provide a suitable spring constant in the longitudinal direction.
  • the spring provides an enclosure within which is mounted a cooperating mass.
  • Figure 1 illustrates the principal elements of the novel telemeter or communication system and of the well drilling apparatus employed for drilling a well bore 36 below the surface 33 of the earth.
  • the drilling apparatus comprises a drill string 35 carrying a drill bit 40 for drilling the bore 36, and the drill string 35 is also simultaneously used as an acoustic propagation medium for telemetering data relative to the progress or state of the drilling operation upward to instruments located above the earth's surface 33.
  • the drilling apparatus of Figure 1 includes a derrick 18 from which is supported the drill string 35 terminated by the drill bit 40.
  • the drill string 35 is suspended by a movable block 13 from a top platform 10 of the derrick 18 and the vertical position of the drill string may be changed by operation of the usual cable loop 12 by a winch 11 suspended from the platform 10.
  • the entire drill string 35 may be continuously rotated by the rotation of a rotary table 20 and a polygonal kelly 16 slidably passing through a correspondingly shaped aperture in the rotary table 20.
  • a motor 17 located on the surface or drilling platform 22 near the rotary table 20, and a shaft 19 are used to drive the table 20 and therefore to rotate the drill string 35.
  • This conventional apparatus may be completed in essential detail by a swivel injector head 14 at the top of the kelly 16 for receiving drilling mud forced through a pipe 15 by a pump located in mud pump apparatus 21.
  • the drilling mud is forced down into the well through the hollow pipe of the drill string 35 and into the working region of the bit 40 for cooling purposes and for removing debris cut out by the bit 40 from the well bore.
  • the used mud and its included debris are returned upwards to the earth's surface 33 in the bore 36, where conventional apparatus (not shown) separates the mud, rejuvenating it for further cycles of use.
  • the portion of the drill string 35 below the earth's surface 33 will generally contain many major sections of threaded-together pipe elements. Near the earth's surface 33 and at the lower part of the drill string 35, there will appear sub-units or pipe-like segments of minor length similarly joined in the drill string and sometimes larger in diameter than the major and much longer elements of the drill string. As has been well established in the art, these sub-units are provided as protective containers for sensors and their ancillary circuits, and for power supplies, such as batteries or conventional mud driven turbines which drive electrical generators or other means to supply electrical energy to operate sensor devices or the like.
  • the drill string 35 serves as an acoustic energy propagation path, whereby data may be telemetered between the bit 40 and surface monitoring apparatus. It will be seen that the drill string 35 has three sub-units adjacent the bit 40, by way of example. In ascending order above the drill bit 40, the first of these is the acoustic isolator sub-unit 39 including a mechanical filter for isolating the communication system from the energetic and wide band noise generated by the drill bit 40 during its actual operation. Such mechanical filters are well known in the prior art, as typified by apparatus disclosed in U.S. Patent No. 4,066,995.
  • next sub-unit 38 is installed in a conventional manner a sensor or sensors adapted to generate an electrical measure or measures of data relating to the operation of the drill bit 40, such as fluid pressure or temperature or the like.
  • the sensor output signals are used to modulate an acoustic transmitter located in the third of the series sub-units 37.
  • pluralities of sensors may be served in this manner by employing multiplexing apparatus such as disclosed in U.S. Patent No. 3,988,896.
  • the vibrations of an acoustic transmitter within the sub-unit 37 are coupled to the drill string 35, thereby exciting a data encoded acoustic wave which propagates towards the earth's surface 33 along the drill string 35.
  • several functions may be performed in the same sub-unit, such as the functions performed in sub-units 37 and 38.
  • a conventional receiver sub-unit 32 for containing a device for receiving the acoustic wave propagating within the drill string 35.
  • the receiver within the sub-unit 32 may be made directional and is adapted to furnish the telemetric data via terminals 31 through a band pass electrical filter 50 of Figure 1A to a display such as a conventional electrical meter 51 or to a suitable recorder 52.
  • a synchronously multiplexed receiver and recorder system such as illustrated in the aforementioned U.S. Patent 3,988,896 may alternatively be employed.
  • a second noise isolation sub-unit 30 which may contain a mechanical filter generally similar to that of the sub-unit 39.
  • the function of the unit 30 is to attenuate vibrations within the pass band of the receiver due to the gear driven rotation of the rotary turn table 17 and to the operation of various other apparatus on the drilling platform 22, including the kelly 16.
  • Acoustic noise within the pass band of the receiver that may arrive at the receiver input as a result of pulsations in the flowing mud generated by the mud pump of the apparatus 21 may also be attenuated by placing a suitable damper (not shown) in the pipe 15.
  • Figures 2 and 3 illustrate in more detail the actual location of the acoustic transmitter within the walls of the acoustic transmitter sub-unit 37.
  • the housing of the sub-unit 37 consists of two cooperating coaxial hollow cylinders 62, 63.
  • the inner cylinder 63 is attached by threads 61 to the lower end of a part 35' of the drill string 35 of Figure 1 and ends at surface 70 at right angles to the axis of the drill string.
  • the outer hollow cylinder 62 has an inner wall 68 which is normally in contiguous relation with the outer surface of the cylinder 63. Furthermore, the outer cylinder 62 is attached by threads 60 to the upper drill string part 35'.
  • the hollow cylinder 63 is equipped with a plurality of circumferentially spaced and axially extending bores, such as the opposed bores or cylindrical cavities 64a, 64b which may be interconnected.
  • the two opposed bores or cavities 6ha, 64b contain active co-phasally driven electric-acoustic transducers 67a, 67b forming the aforementioned transmitters, while other of the bores (shown in Figure 3) may be used as locations for other down-well equipment or for conventional vibration-driven power supplies or batteries for activating those various electronic elements, including apparatus associated with the acoustic transducers.
  • the opposed bores 64a, 64b contain respective electric-acoustic transducers 67a and 67b.
  • the transducer 67a within the bore 64a includes a piezoelectric driver 66a ( Figure 4) and resonating mass system 90,91,96, both supported in colineal relation by a threaded bolt 86 the upper threads 65a of which extend into a threaded bore 80 at the upper internal end of the bore 64a.
  • a ring-shaped end piece 72 is provided fitting against the end 70 of the cylinder 63.
  • the ring 72 is equipped with circumferentially spaced circular bosses (such as bosses 71a, 71b)which extend into the respective bores (such as 64a, 64b), thereby excluding contaminants.
  • the ring 72 may be permanently or semi-permanently affixed to the end 70, as desired. Other closure means may be used.
  • the outer hollow cylinder 62 is equipped with threads 75 at its lower end to enable the sub-unit 37 to be coupled to the next lowest part 35" of the drill string 35.
  • the drill string part 35" is equipped with a flat upper surface 74 perpendicular to its central longitudinal axis.
  • an 0-ring 73 or equivalent sealing member is compressed by the surface 74 into an annular 0-ring seat disposed in the lower annular face of the ring 72.
  • the 0-ring may be dispensed with, the surface 74 engaging the lower planar surface of the ring 72.
  • the assembly permits successful successive coupling and uncoupling of the sub-unit 37 between the drill string parts 35', 35", the inner cylinder 63 containing and protecting the acoustic transmitter system and the outer cylinder 62 cooperating in the same function and also serving as the primary load- bearing connection between the drill string parts 35', 35".
  • the Figure 2 transducer 67a and its containing cylinder 63 may be inverted so that the bore 64a points upwardly and so that the transducer 67a projects upwardly from a corresponding bolt having threads 65a.
  • the dimensions and proportions in the various figures have been distorted in the interests of making the drawings clear and that the proportions illustrated would not necessarily be used in practice.
  • the transducer 67a was about 2.5cm (1 inch) in diameter, its overall length about 45cm (1.5 feet), and the mass-spring resonator was about 60cm (2 feet) long.
  • the transducers 67a, 67b of Figure 2 each take the form shown in more detail in Figure 4; as shown in Figures 2 and 4, each such transducer is suspended by the headless bolt 86, the upper threads 65a of which are threaded into the bore 80 within the top surface of a wall of the hollow cylinder 63.
  • the bolt 86 extends through the generally conventional sonic piezoelectric wave exciter or driver 66a including, as will be further discussed, an assembly of piezoelectric discs.
  • the piezoelectric discs of the driver 66a are maintained in axial compression between apertured insulator end discs 81, 84.
  • the hollow internally threaded part 85 is rotated on the threads of the bolt 86 until the stack of ceramic high dielectric discs within the piezoelectric driver 66a experiences the desired level of compression.
  • the threaded steel part 85 may then be fixed against further rotation with respect to the threads of the bolt 86 in any convenient manner. If desired, the upper threads 65a of the headless bolt 86 may be pinned in the same manner, but with respect to the wall of the cylinder 63.
  • the bolt 86 is made of age-hardened, high strength, low thermal expansion alloy such as a corrosion resistant alloy of nickel, iron, and chromium sold as type 903 under the trademark Incoloy by the International Nickel Company of U.S.A.
  • age-hardened, high strength, low thermal expansion alloy such as a corrosion resistant alloy of nickel, iron, and chromium sold as type 903 under the trademark Incoloy by the International Nickel Company of U.S.A.
  • the threaded steel part 85 forms a suspension for a spring-mass system which is vibrated vertically (i.e. longitudinally) by the piezoelectric driver 66a.
  • a hollow tube 87 has an end section 87a whose inner diameter matches the outer diameter of the part 85 and is welded or otherwise permanently affixed thereto.
  • a bellows-like corrugated section 89 which forms an active axial spring for the system.
  • the spring bellows 89 and its opposite constant diameter ends 87a,87b are preferably formed of a stainless steel tubing with its mid-section 89 swaged into a regular multiply corrugated shape for providing the required longitudinal spring action along the spring axis.
  • Characteristic of the spring section 89 is the fact that it desirably retains substantially the same lateral rigidity as is present in the original tube itself.
  • the inner diameter of the tube section matches the outer diameter of a section 90 of the suspended mass system 90, 91, 96 and is fastened permanently thereto, as by welding.
  • a tapered portion 95 integral with the section 90 extends above it and integrally supports a mass element 96 whose diameter is designed to clear the inner surface of the bellows spring 89.
  • the lower end portion 91 of the mass system 90, 91, 96 has an expanded diameter relative to portions 90, 96, but slidably clears the inner surface of the bore 64a in the cylinder 63.
  • Affixed in a ring-shaped depression in the mass part 91 is an annular bearing 92 constructed of hardened steel, lubricated upon assembly.
  • bearing surface provided moves axially in relatively friction- free manner in contact with the steel surface of the circular bore 64a.
  • Another annular bearing 94 is permanently affixed to the inner wall of the unconvoluted end 87a of the tube 87 so that the free end of the mass 96 may slide easily therewithin and so that the mass 96 does not contact the bellows spring 89.
  • Bearings 92 and 94 are preferably of hardened steel.
  • the end portion 91 of the mass system is conveniently fitted with an integral hexagonal bolt head 93 to facilitate inserting and withdrawing the assembly from the threaded bore 80.
  • the integrated mass system 90, 91, 96 may be constructed of steel, though other materials may be found suitable. Sintered or solid tungsten, because of its high density, is specially suitable. Certain known tungsten-copper alloys are also possible materials.
  • An additional advantage of the configuration shown in Figure 4 lies in the re-entrant disposal of the mass elements 90, 91, 95, 96 into the interior of the bellows spring portion 89, making full use of available space and making it possible for the length of the transmitter and of the bores 64a, 64b, to be shortened, thus decreasing the overall length of the sub-unit 37 and its cost.
  • a generally conventional piezoelectric driver system may be employed as the sonic driver 66a to produce axial vibrations when an alternating voltage is coupled to leads 82, 83 of Figure 4.
  • the discs making up the driver 66a are prepared and assembled following prior art practice such as widely discussed in the literature.
  • a stack of about 200 ceramic apertured discs such as disc 123 is employed, each disc having a 2.2cm ( 7 8 inch) outside diameter and a centred lcm ( 3 8 inch) hole.
  • the discs are formed of PZT 5550 material readily available commercially.
  • each disc 123 The opposed faces of each disc 123 are optically lapped and supplied with a sputtered chromium layer such as layers 122, 124 adhered to the ceramic surface and then an electrically conductive gold layer such as layers 121, 125 readily adhesive to the chromium.
  • a sputtered chromium layer such as layers 122, 124 adhered to the ceramic surface and then an electrically conductive gold layer such as layers 121, 125 readily adhesive to the chromium.
  • thin conductive plates such as the apertured plates 120, 126 are interposed. Alternate ones of these plates, such as plate 126, are coupled to one terminal of the a.c. driving power source by a tab 127, while the intervening plates, such as plates 120, 130, are similarly coupled to the second terminal of that driving power source.
  • the total stack of the ceramic discs 123 is electrically in parallel when driven, but yields serial or axial cyclic longitudinal expansion and contraction.
  • a conventional insulating or protective tape may be wrapped
  • a power supply and control suitable for driving two of the transducer drivers 66a, 66b of Figure 4 are shown, the two drivers being connected in parallel and then in series through an electrically resonating inductance 100 to the output of a power amplifier 101.
  • the amplifier 101 may be driven by a conventional tunable oscillator 102 operating in the general region of 400 Hz., for example.
  • the oscillator 102 may be put into action by a time programmed switch 104 which may be controlled through a mechanical link 105 by a conventional programmer 106 operated by a clock 108 via a mechanical link 107.
  • a time programmed switch 104 which may be controlled through a mechanical link 105 by a conventional programmer 106 operated by a clock 108 via a mechanical link 107.
  • economical use may be made of a d.c. supply or battery 103, since the transducer system needs to be operated periodically for only a fraction of a minute in order to convey sufficient data to the earth's surface.
  • the arrangement makes it easy to start the clock 108 as the sub-unit 37 is inserted at the earth's surface into the drill string 35 to be lowered into the well.
  • data sensed by a sensor such as a pressure pick-off 109 may be coded by well known means and supplied as an intelligence bearing modulation by a modulator 112 to the carrier frequency generated by the oscillator 102 in the general manner taught, for instance, in the aforementioned U.S. Patent No. 3,988,896.
  • Additional pick-offs or sensors 110, 111 may be used in a similar manner to convey data to the earth's surface for display or recording purposes employing the concepts of U.S. Patent No. 3,988,896 for synchronous multiplexing and demultiplexing of the data.
  • the sensors 109, 110, 111 may provide information on pressure, temperature, or other variables.
  • the piezoelectric driver 66a is electrically capacitive (C) so that inductor 100 (L) is made adjustable to the appropriate value, giving a resonance frequency F 1 : Where two transducers are in parallel, the value C will, of course, be the effective capacitance of the parallel connected transducers.
  • the series inductance 100 has the effect of amplifying the voltage across the drivers 66a, 66b in proportion to the quality factor Q of the circuit.
  • the electrical resonance is complemented by the mechanical resonance across each piezoelectric driver 66a, 66b.
  • the mechanical loading of the piezoelectric stack with the stiff spring 89 and the extended mass makes use of the stack compliance and the spring compliance to aid in controlling the free vibration of the mass.
  • the mechanical resonance frequency F 2 for a mass of M kilograms and a proportionality constant K in Newtons per metre is readily calculated as: Since the spring 89 contributes about one third of its mass m to the inertia of the moving system, this contribution must be accounted for in the equation for F 2 0
  • the mass-spring combination permits resonant operation of the piezoelectric transducer and is a useful means for extending the mechanical resonance of the piezoelectric system to lower frequencies than is conventionally possible.
  • the selected resonant frequency may be lower than previously, in the frequency range within which acoustic transmission losses in the drill string are favourably lowest.
  • the transducer will serve as an acoustic receiving transducer equally as well as a transmitter of acoustic waves.
  • FIG. 5 shows a first modified construction of the transducer 67a, parts similar to those of Figure 4 being given the same reference numerals.
  • each transducer 67a of Figure 5 is suspended by a headless bolt 86 having upper threads 85 threaded into a bore 80 within the top surface of the wall of the hollow cylinder 63.
  • the bolt 86 extends through the conventional wave exciter or driver 66a of the form shown in Figure 7.
  • the bolt 86 is threaded in a bore 88 of a cooperating steel part 85.
  • the threaded steel part 85 is secured against rotation with respect to the threads of the bolt 86 by the insertion of a taper pin 87 in a conventional manner.
  • the upper end of the headless bolt 86 may be pinned in the same manner, but with respect to the wall of the cylinder 63.
  • the bore 88 continues into the start of an extended steel rod 187 which forms a major part of a vibratable mass. Before ending in the principal mass 180, the bore 88 cooperates in forming a stiff helical spring 389 with a generally rectangular cross section, formed by using any suitable machining process to cut away metal between turns from the start of the helix at 190 to its end at 191 all of the way into the bore 88.
  • the steel spring 89 and the mass of the steel rod 187 cooperate in defining the resonance characteristics of a mechanical vibratory system which is to cooperate with an electrically resonant system employing the effective capacitance of the piezoelectric array and a cooperating series inductor shown generally at 100 in Figure 8.
  • the vibratory system is supported at the top of bolt 86 and is further restricted so that its axis remains coincident with the axis of the bore 64a, This latter is accomplished by the use of three hardened steel bearings 195a, 195b, and 195c having lubricated bearing surfaces extending radially at the lower end of the rod mass 180. Equally spaced about the circular cylindrical surface of the rod 187, their bearing surfaces move in relatively friction free fashion in contact with the steel surface 198 of the circular bore 64a, The lower end 196 the steel bar mass 180 is conveniently cut to form a hexagonal bolt head 197 to facilitate inserting and withdrawing the assembly from the bore 80.
  • the part 85, the helical spring 189, and the mass 180 may be made of high quality spring steel, although other materials may be found suitable. Solid or sintered tungsten, because of its high density, is also of interest, and alloys of tungsten compounded with copper.
  • the accelerometer 294 of Figure 6 is again shown mechanically affixed directly to the driving transmitter of the transducer 67a.
  • the output of the accelerometer 294 is coupled via lead 301 to junction 299 of an input biasing network including the grounded bias resistor 300 and then into a preamplifier 302 supplied in the usual manner via power input terminals 303, 304.
  • the second cooperating terminal of preamplifier 202 is coupled in the feedback network at junction 308 wherein capacitor 307 and resistor 306 are series coupled to ground and through the parallel disposed capacitor 305 and resistor 309 coupled to junction 310.
  • the circuit associated with the preamplifier 302 serves as a high impedance buffer stage and provides gain control.
  • the preamplifier output is fed from the junction 310 through the signal terminals of field effect transistor 325 to one input terminal of amplifier 332, the other input 311 of which is grounded.
  • Amplifier 332 is supplied with the usual power input terminals 330, 331 and with a variable feedback network including capacitors 327,333 and variable resistor 328, and provides a useful output at terminal 332a.
  • Amplifier 332, together with the series coupled preamplifiers 34o and 361 caaperate to limit the band width of the signal.
  • Amplifier 340 whose input at 335 is provided through junction 332a and resistor 334, is provided with power at terminals 337, 338, has a feedback capacitor 339, a feedback resistor 336, and an output coupled through variable resistor 356 to an input of amplifier 361.
  • Amplifier 361 has feedback capacitors 357 and 360, together with the usual power inputs 359 and 362. Its output on lead 363 and terminal 358 is fed back through variable resistor 354 and lead 326 to the input terminal 329 of the aforementioned amplifier 332.
  • Variable resistors 354, 356 are gang coupled by linkage 3550
  • Amplifier 332 is coupled as an integrator, amplifier 340 as an inverter, and amplifier 361 as a second integrator so that a differentiated form of the input at 329 appears on feedback lead 326.
  • Control of network 327, 328 determines the gain-band width of the active filter assembly of amplifiers, while the adjustable resistors 354, 356 set the centre frequency of the effective filter pass band. This pass band encompasses the mechanical resonance peaks of the transmitter of transducer 67a, together with the maximum anticipated drift from that centre frequency.
  • the useful output of amplifier 332 at terminal 332a is coupled via lead 404 and resistor 405 to one input 432 of power amplifier 435 having the usual supply terminals 433, 436 and a feedback capacitor 434 and resistor 430.
  • the second input to power amplifier 435 is coupled through resistor 411 to ground.
  • the amplified power output at terminal 431 is coaled via lead 364 to operate the transmitter of the transducer 67a.
  • the useful output of amplifier 332 at terminal 332a is coupled through resistor 402 and blocking capacitor 403 to a terminal 406 which is the input to a rectifier circuit.
  • the latter includes diodes 401, 407 poled as shown, with a cooperating filter including capacitor 400 and resistor 390.
  • the output of the rectifier on lead 388 passes into one terminal of direct current amplifier 383 having a feedback capacitor 382 and biasing resistor 384.
  • Amplifier 383 acts as an active gain-limiting element in an automatic gain control circuit and is supplied with power via terminals 386, 387.
  • junction 385 Its output at junction 385 is fed through blocking diode 381 to junction 380 for supply through resistor 379 to ground and through resistor 378 via lead 377 to the current control biasing gate electrode of field effect transistor 325.
  • the second input of d.c. amplifier 383 is supplied with a bias signal by virtue of potentiometer 410, lead 437, capacitor 408, and a power source (not shown) coupled to terminal 409 of potentiometer 410.
  • the automatic gain control loop is completed; the system will oscillate at a frequency at which the loop gain is unity and phase shift is zero. If the loop gain is greater than unity, the amplitude of oscillation automatically increases until some element in the loop shows non-linear behaviour. To avoid consequent generation of a non-linear waveform, the automatic gain control circuit adjusts the gain to produce a constant amplitude purely sinusoidal output.
  • the network found in Figure 10 between junction 310 and the bias gate electrode of the gain controlling field effect transistor 325 acts as a distortion minimizing network, changing the bias on the field effect transistor gate electrode as the waveform goes below the zero level. It includes a voltage divider comprising resistor 370, variable resistor 375, and capacitor 376, the centre tap 371 between resistors 370, 375 being coupled through a clipper diode 372 to the tap 374.a of a potentiometer 374. A bias is supplied through tap 374a by coupling potentiometer 374 between ground and resistor 373, one terminal 369 of which is coupled to a negative voltage source (not shown).
  • the accelerometer 294 is again shown mechanically affixed directly to the driving transmitter of the transducer 67a.
  • the output of the accelerometer 294 is coupled via lead 460 across input resistor 461 to one input of an amplifier 463 having the usual power supply inputs 462, 464.
  • the second cooperating terminal of preamplifier 463 is coupled in a feedback network at junction 459 wherein capacitor 465 is coupled through the variable gain controlling resistor 466 to ground.
  • the output terminal 468 of amplifier 463 is coupled through resistor 467 to input junction 459.
  • the output of amplifier 463 may be corrected for phase compensation purposes before lowering the equipment into the well by the manual positioning of switch 469 so as to select an appropriate one of two inputs to the conventional phase detector 478.
  • the signal at junction 468 may be injected into detector 478 through an R-C path (provided by a capacitor 470 and a resistor 472) or through a second R-C path (provided by a capacitor 471 and a resistor 473) having distinctive parameters.
  • the input signal is compared in phase detector 478 to a fed back signal on lead 279.
  • phase detector 478 is a bipolar direct current signal used to control the frequency of a conventional current-controlled oscillator 506 which operates in locked-oscillator fashion to supply alternating power via terminal 511 to drive the transducer 67a.
  • the bipolar direct current is filtered by R-C network provided by resistor 480 and capacitor 481 and is applied via input resistor 505 to the control terminal of oscillator 506.
  • the adjustable resistor network 507 is a conventional part of oscillator 510 and is provided for the purpose of setting the free running frequency within the locking range of the phase-locked loop.
  • the adjustable resistor 507 operates in conjunction with capacitor 508 for this purpose.
  • the output terminal 511 of oscillator 506 is supplied with a positive potential through resistor 509 from a power supply (not shown) at terminal 513.
  • Terminal 511 is coupled via lead 512 to one input of amplifier 500, supplied with power input terminals 489,490.
  • the output terminal 485 of power amplifier 500 is coupled to the input of the transmitter of the transducer 67a. It is also connected to ground through resistors 486, 487 having a common junction 488, which terminal 488 is coupled back to the second input terminal of power amplifier 500.

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  • Physics & Mathematics (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Acoustics & Sound (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Remote Sensing (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Apparatuses For Generation Of Mechanical Vibrations (AREA)
EP19810300068 1980-01-21 1981-01-08 System zur akustischen Datenweiterleitung entlang einem Bohrloch-Gestängestrang Ceased EP0033192A1 (de)

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
US06/114,040 US4282588A (en) 1980-01-21 1980-01-21 Resonant acoustic transducer and driver system for a well drilling string communication system
US06/114,038 US4283780A (en) 1980-01-21 1980-01-21 Resonant acoustic transducer system for a well drilling string
US114038 1980-01-21
US06/114,039 US4302826A (en) 1980-01-21 1980-01-21 Resonant acoustic transducer system for a well drilling string
US114039 1980-01-21
US114040 1987-10-29

Publications (1)

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EP0033192A1 true EP0033192A1 (de) 1981-08-05

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EP19810300068 Ceased EP0033192A1 (de) 1980-01-21 1981-01-08 System zur akustischen Datenweiterleitung entlang einem Bohrloch-Gestängestrang

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Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2638471A1 (fr) * 1988-11-02 1990-05-04 Ingenierie Genie Civil Sarl Dispositif de mesure de pression pour le betonnage de trous fores
WO1992006278A1 (en) * 1990-09-29 1992-04-16 Metrol Technology Limited Transmission of data in boreholes
GB2258331A (en) * 1991-07-31 1993-02-03 Marconi Gec Ltd Data transmission
WO1996024751A1 (en) * 1995-02-09 1996-08-15 Baker Hughes Incorporated An acoustic transmisson system
WO1999020987A1 (en) * 1997-10-20 1999-04-29 Maycom Communications Ltd. A resonator for the acoustic transmission of information and a system utilizing same
US6442105B1 (en) 1995-02-09 2002-08-27 Baker Hughes Incorporated Acoustic transmission system
US6843120B2 (en) 2002-06-19 2005-01-18 Bj Services Company Apparatus and method of monitoring and signaling for downhole tools
US8437220B2 (en) 2009-02-01 2013-05-07 Xact Downhold Telemetry, Inc. Parallel-path acoustic telemetry isolation system and method
US9458712B2 (en) 2009-02-13 2016-10-04 Xact Downhole Telemetry, Inc. Acoustic telemetry stacked-ring wave delay isolator system and method
EP2072829B2 (de) † 2007-12-21 2017-12-20 Grundfos Management A/S Tauchpumpe

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3845837A (en) * 1972-10-30 1974-11-05 Texaco Inc Gravity force operated apparatuses for generation of longitudinal pulse data from the bottom of a well
US3930220A (en) * 1973-09-12 1975-12-30 Sun Oil Co Pennsylvania Borehole signalling by acoustic energy
US3988896A (en) * 1975-05-23 1976-11-02 Sperry Rand Corporation Geothermal energy pump and monitor system
US4066995A (en) * 1975-01-12 1978-01-03 Sperry Rand Corporation Acoustic isolation for a telemetry system on a drill string
US4139836A (en) * 1977-07-01 1979-02-13 Sperry-Sun, Inc. Wellbore instrument hanger

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3845837A (en) * 1972-10-30 1974-11-05 Texaco Inc Gravity force operated apparatuses for generation of longitudinal pulse data from the bottom of a well
US3930220A (en) * 1973-09-12 1975-12-30 Sun Oil Co Pennsylvania Borehole signalling by acoustic energy
US4066995A (en) * 1975-01-12 1978-01-03 Sperry Rand Corporation Acoustic isolation for a telemetry system on a drill string
US3988896A (en) * 1975-05-23 1976-11-02 Sperry Rand Corporation Geothermal energy pump and monitor system
US4139836A (en) * 1977-07-01 1979-02-13 Sperry-Sun, Inc. Wellbore instrument hanger

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2638471A1 (fr) * 1988-11-02 1990-05-04 Ingenierie Genie Civil Sarl Dispositif de mesure de pression pour le betonnage de trous fores
WO1992006278A1 (en) * 1990-09-29 1992-04-16 Metrol Technology Limited Transmission of data in boreholes
AU649071B2 (en) * 1990-09-29 1994-05-12 Metrol Technology Limited Transmission of data in boreholes
US6912177B2 (en) 1990-09-29 2005-06-28 Metrol Technology Limited Transmission of data in boreholes
GB2258331A (en) * 1991-07-31 1993-02-03 Marconi Gec Ltd Data transmission
WO1996024751A1 (en) * 1995-02-09 1996-08-15 Baker Hughes Incorporated An acoustic transmisson system
US6442105B1 (en) 1995-02-09 2002-08-27 Baker Hughes Incorporated Acoustic transmission system
WO1999020987A1 (en) * 1997-10-20 1999-04-29 Maycom Communications Ltd. A resonator for the acoustic transmission of information and a system utilizing same
US6843120B2 (en) 2002-06-19 2005-01-18 Bj Services Company Apparatus and method of monitoring and signaling for downhole tools
EP2072829B2 (de) † 2007-12-21 2017-12-20 Grundfos Management A/S Tauchpumpe
US8437220B2 (en) 2009-02-01 2013-05-07 Xact Downhold Telemetry, Inc. Parallel-path acoustic telemetry isolation system and method
US9458712B2 (en) 2009-02-13 2016-10-04 Xact Downhole Telemetry, Inc. Acoustic telemetry stacked-ring wave delay isolator system and method

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