EP0140788A2 - Druckimpulsgenerator - Google Patents

Druckimpulsgenerator Download PDF

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Publication number
EP0140788A2
EP0140788A2 EP84402124A EP84402124A EP0140788A2 EP 0140788 A2 EP0140788 A2 EP 0140788A2 EP 84402124 A EP84402124 A EP 84402124A EP 84402124 A EP84402124 A EP 84402124A EP 0140788 A2 EP0140788 A2 EP 0140788A2
Authority
EP
European Patent Office
Prior art keywords
rotor
stator
lobes
fluid
sides
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.)
Withdrawn
Application number
EP84402124A
Other languages
English (en)
French (fr)
Other versions
EP0140788A3 (de
Inventor
Jose A. Trevino
Wilson C. Chin
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.)
Schlumberger Technology Corp
Original Assignee
Schlumberger Technology 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
Application filed by Schlumberger Technology Corp filed Critical Schlumberger Technology Corp
Publication of EP0140788A2 publication Critical patent/EP0140788A2/de
Publication of EP0140788A3 publication Critical patent/EP0140788A3/de
Withdrawn legal-status Critical Current

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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
    • 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
    • E21B47/18—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 well fluid, e.g. mud pressure pulse telemetry
    • 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
    • E21B47/18—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 well fluid, e.g. mud pressure pulse telemetry
    • E21B47/20—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 well fluid, e.g. mud pressure pulse telemetry by modulation of mud waves, e.g. by continuous modulation

Definitions

  • the present invention relates to pressure pulse generators in general, and in particular to pressure pulse generators such as the "mud siren" type used in oil industry MWD (measurements-while-drilling) operations to transmit downhole measurement information to the well surface during drilling by way of a mud column located in a drill string.
  • pressure pulse generators such as the "mud siren" type used in oil industry MWD (measurements-while-drilling) operations to transmit downhole measurement information to the well surface during drilling by way of a mud column located in a drill string.
  • a typical such modulator is comprised of a fixed stator and a motor-driven rotatable rotor, positioned coaxially of each other.
  • the stator and rotor are each formed with a plurality of block-like radial extensions or lobes spaced circumferentially about a central hub so that the gaps between adjacent lobes present a plurality of openings or ports to the oncoming mud flow stream.
  • the respective ports of the stator and rotor are in direct alignment, they provide the greatest passageway for flow of drilling mud through the modulator.
  • the lobe configuration and the relative placement of the stator and rotor elements of conventional modulators is such as to subject the rotor to fluid dynamic forces due to the mud stream that cause the rotor to seek a "stable closed" position in which the lobes of the rotor block the ports of the stator.
  • the modulator There is thus an undesirable tendency for the modulator to assume a position that blocks the free flow of drilling mud whenever the rotor becomes even temporarily inoperative. This increases the likelihood that the modulator will jam, as solids carried by the mud stream are forced to pass through restricted modulator passages.
  • Rotor restart is made more difficult because the reduced mud flow interferes with the generation of rotor power by the mud turbine below.
  • Prolonged modulator closing can obstruct mud flow to such an extent that lubrication of the drill bit and other vital functions of the mud become so adversely affected, that the entire drilling operation is jeopardized.
  • a system for avoiding such jamming includes control means responsive to conditions tending to slow the motor (such as an increase in pressure differential across the modulator or an increase in driving torque requirement) for temporarily separating the rotor and stator in order to allow debris to be cleared from the modulator by the flowing mud.
  • Such a system can be employed to provide some relief from the decreased mud flow experienced with a closed modulator by separating the modulator parts in response to the pressure differential increase experienced when the modulator assumes a closed position.
  • the present invention provides an improved pressure pulse generator or modulator of the type used for communicating information between points of a wellbore by way of fluid flowing in a tubing string which includes a housing adapted to be connected in the string so that fluid flowing in the string will at least partially flow through the housing; a stator fixedly mounted within the housing; and a rotor rotatably mounted within the housing adjacent to the stator; the stator and rotor each having a plurality of spaced lobes with gaps formed therebetween that present a plurality of ports for fluid passage such that rotation of the rotor relative to the stator will shift alignment of the respective stator and rotor ports from a position providing the greatest fluid passageway to a position providing the least fluid passageway, so that fluid flow through the housing will be interrupted to cause the generation and transmission upstream of a pressure pulse signal.
  • the invention is characterized in one of its aspects by means responsive to the flow of fluid in the string for establishing fluid dynamic forces that bias the generator into a stable open position.
  • a pressure pulse generator structured in accordance with one aspect of the present invention comprises a fixed stator and a rotatable rotor both mounted within a housing adatpted to be connected in a tubing string so that fluid flowing in the string will at least partially flow through the housing.
  • the rotor is mounted adjacent to and downstream of the stator.
  • Both stator and rotor are formed to have a plurality of radial extensions or lobes, with intervening gaps between adjacent lobes serving to present a plurality of ports or openings for the passage of fluid flowing through the housing.
  • Rotation of the rotor relative to the stator will vary the blocking effect of the rotor extensions to flow issuing from the stator ports, shifting the relative alignment of the respective stator and rotor ports between a position providing the greatest passageway for fluid flow through the housing ("open” position) and a position providing the least passageway for fluid flow through the housing ("closed” position).
  • THis valve action interrupts fluid flow in such a manner as to cause the generation and transmission through the flowing fluid upstream of a pulse pulse signal.
  • the relative placement of the stator and rotor and the specific configuration of their respective lobes are such that fluid dynamic forces are established in response to the flow of fluid in the housing that bias the rotor into an orientation providing the greatest fluid passageway through the generator. Should the generator fail or otherwise become inoperative, fluid forces will urge it into a position of minimum flow blockage.
  • each lobe of the rotor with sides outwardly tapered in the downstream direction and with underlap relative to the stator lobes.
  • the taper of each side on the rotor lobes is preferably in the range of about 8° to 30° with respect to a vertical axis.
  • the rotor lobes are configured in such a manner as to cause the rotor to oscillate between an open position and a partially closed position due to fluid dynamic action. This serves to prevent debris from blocking the flow of fluid through the modulator and provides a periodic motion and signal whose frequency varies with flowrate.
  • the oscillation takes the form of aerodynamic flutter created by providing the sides of each rotor lobe with reduced width, untapered regions at their trailing edges adjacent to the base of the lobe.
  • the sides of the rotor lobes may also be provided with untapered regions at their leading edges adjacent to the top of the lobe so as to provide a cutting action upon debris passing into the ports and into the gap between the stator and rotor.
  • the modulator of the present invention provides an improved signal source having good obstruction avoidance capabilities. It has particular application in the oil industry in measurements-while-drilling, well testing and completed well monitoring operations as a signal source for communications from downhole to surface, from surface to downhole, or between intermediate points of a well. Other applications include its use as a sound source for underwater seismological explorations, use as a flow monitoring device and use as a unidirectional flow valve.
  • Fig. 1 of the drawings shows a tubular measurements-while-drilling (MWD) tool 20 connected in a tubular drill string 21 having a rotary drill bit 22 coupled to the end thereof and arranged for drilling a borehole 23 of a well through various earth formations.
  • MWD tubular measurements-while-drilling
  • a suitable drilling fluid known as "drilling mud”
  • the mud is returned to the surface up along the annular space existing between the walls of the borehole 23 and the exterior of the drill sting 21.
  • the circulating mud stream flowing through the drill string 21 serves as a medium for transmitting pressure pulse signals carrying information from the MWD tool 20 to the surface, as described more fully below.
  • a downhole data signaling unit 24 has transducers mounted on the tool 20 that take the form of one or more condition responsive devices 26 and 27 coupled to appropriate data encoding electrical circuitry, such as an encoder 28, which sequentially produces encoded digital data electrical signals representative of the measurements obtained by the transducers 26 and 27.
  • the transducers 26 and 27 are selected and adapted as required for the particular application to measure such downhole parameters as the downhole pressure, the temperature, and the resistivity or conductivity of the drilling mud or adjacent earth formations, as well as to measure various other downhole conditions similar to those obtained by present day wireline logging tools.
  • Electrical power for operation of the data signaling unit 24 is provided by a typical rotatably-. driven axial flow mud turbine 29 which has an impeller 30 responsive to the flow of drilling mud that drives a shaft 31 to produce electrical energy.
  • the data signaling unit 24 also includes a modulator 32 which is driven by a motor 35 to selectively interrupt or obstruct the flow of the drilling mud through the drill string 21 in order to produce digitally-encoded pressure pulses in the form of acoustic signals.
  • the modulator 32 is selectively operated in response to the data-encoded electrical output of the encoder 28 to generate a correspondingly encoded acoustic signal.
  • This signal is transmitted to the well surface by way of the fluid flowing in the drill string 21 as a series of pressure pulse signals which preferably are encoded binary representations of measurement data indicative of the downhole drilling parameters and formation conditions sensed by the transducers 26 and 27. When these signals reach the surface, they are detected, decoded and converted into meaningful data by a suitable signal detector 36, such as shown in U.S. Patents 3,309,656; 3,764,968; 3,764,969; and 3,764,970.
  • the modulator 32 includes a fixed stator 40 and a rotatable rotor 41 which is driven by the motor 35 in response to signals generated by the encoder 28. Rotation of the rotor 41 is controlled in response to the data-encoded electrical output of the encoder 28 in order to produce a correspondingly encoded acoustic output signal. This can be accomplished by applying well-known techniques to vary the direction or speed of the motor 35 or to controllably couple/uncouple the rotor 41 from the drive shaft of the motor 35.
  • the stator 40 has a plurality of evenly- spaced block-like lobes 71 circumferentially arranged about a central hub.
  • the gaps between adjacent lobes 71 provide a plurality of ports to pass the incident drilling mud through the stator as jets or streams directed more or less parallel to the stator hub axis.
  • the rotor 41 has a similar configuration to that of the stator 40 and is positioned adjacent to and downstream of the stator for rotation about an axis coaxial with the hub axis of the stator.
  • the resulting acoustic signal When the rotor 41 is rotated in relation to the stator 40 so as to momentarily present the greatest flow obstruction to the circulating mud stream, the resulting acoustic signal will be at its maximum amplitude. As the rotor 41 continues to rotate, the amplitude of the acoustic signal produced by the modulator 32 will decrease from its maximum to its minimum value as the rotor moves to a ppsition in which it presents the least obstruction to the mud flow. Further rotor rotation will cause a corresponding increase in signal amplitude as the rotor again approaches its next maximum flow obstruction position.
  • rotation of the modulator rotor 41 will produce an acoustic output signal having a cyclic waveform with successively alternating positive and negative peaks referenced about a mean pressure level.
  • Continuous rotation of the rotor 41 will produce a typical alternating or cyclic signal at a designated frequency which will have a determinable phase relationship in relation to some other alternating signal, such as a selected reference signal generated in the circuitry of the signal detector 36.
  • the rotor can be selectively shifted to a different position vis-a-vis the stator 40 than it would have occupied had it continued to rotate without change.
  • This selective shifting causes the phase of the acoustic signal to shift relative to the phase of the reference signal.
  • Such controlled phase shifting of the signal generated by the modulator 32 acts to transmit downhole measurement information by way of the mud column to the well surface for detection by the signal detector 36.
  • a shift in phase at a particular instance signifies a binary bit "1" (or "0") and absence of a shift signifies a binary bit "0” (or “1”).
  • Other signal modulation techniques are usable, and selection of the specific encoding, modulation and decoding schemes to be employed in connection with the operation of the modulator 32 are matters of choice, detailed discussion of which is unnecessary to an understanding of the present invention.
  • both the stator 40 and the rotor 41 are mounted within a tubular housing 42 which is force-fitted within a portion of a drill collar 43 by means of enlarged annular portions 44 and 45 of the housing 42 which contact the inner surface of the drill collar 43.
  • a plurality of "O"-rings 46 and 47 provide sealing engagement between the collar 43 and the housing 42.
  • the stator 40 is mounted by way of threaded connections 50 (see also Fig. 4b) to an end of a supporting structure 51 centrally located within the housing 42 and locked in place by a set screw 56.
  • the space between the end of the threaded portion of the stator 40 and an adjacent shoulder of the supporting structure 51 is filled with a plurality of "O"-rings 55.
  • the supporting structure 51 is maintained in spaced relationship to the inner walls of the housing 42 by means of a front standoff or spider 52.
  • the standoff 52 is secured to the supporting structure 51 by way of a plurality of hex bolts 53 (only one of which is shown) and, in turn, secured to the housing 42 by a plurality of hex bolts 54 (only one of which is shown).
  • the front standoff 52 is provided with a plurality of spaced ports to permit the passage of drilling fluid in the annular space formed between the supporting structure 51 and the inner walls of the housing 42.
  • the rotor 41 is mounted for rotation on a shaft 60 of the motor 35 (Fig. 1) which drives the rotor 41.
  • the rotor 41 has a rotor bushi.ng 59 (Fig. 2) keyed near the end of the shaft 60 and forced into abutment with a shoulder 61 of the shaft 60 by a bushing 62 also keyed to the end of the shaft 60.
  • the bushing 62 is forced against the rotor bushing 59 by means of a hex nut 63 threaded to the free end of the shaft 60.
  • An inspection port 58 is provided for examining the stator and rotor lobes 71, 72 to measure rotor-stator spacing and to detect wear.
  • the shaft 60 is supported within a bearing housing 65 for rotation about a bearing structure 66.
  • the bearing housing 65 is supported in spaced relationship to the inner walls of the housing 42 by way of rear standoff or spider 67 secured to the bearing housing by way of hex bolts 68 and, in turn, secured to the housing 42 by way of hex bolts 69.
  • drilling fluid flows into the top of the housing 42 in the direction indicated by arrows 70 (Fig. 2) through the annular space between the external wall of the supporting structure 51 and the inner walls of the housing 42 and flows through ports of the stator 40 and the rotor 41.
  • the fluid flow continues past the rear standoff 67 and on to the drill bit 22 (Fig. 1).
  • the shaft 60 drives the rotor 41 to interrupt the fluid jets passing through the ports of the stator 40 to generate a coded acoustic signal that travels upstream.
  • the rotor 41 is positioned downstream of the stator 40 and its lobes 72 are configured to provide fluid dynamic forces in response to the mud flow which drive the rotor 41 to an open position relative to the stator 40 whenever the rotor 41 is not being driven by the motor 35. More specifically, the relative geometry and placement of the stator 40 and the rotor 41 establishes fluid dynamic biasing of the rotor 41 into an orientation in which the lobes 72 of the rotor 41 provide the least obstruction to fluid flowing through the ports of the stator 40.
  • Figs. 3a-5c show the features of a first embodiment of modulator 32 that exhibits such "stable open” behavior.
  • Fig. 6 identifies dimensions useful in understanding these features.
  • stator 40 The general relationship between the stator 40 and the rotor 41 of the modulator 32 is shown in Fig. 3a. As indicated by the arrows, drilling mud flows through the housing 42 in the downhole direction and rotation of the rotor 41 generates an acoustic signal that is transmitted uphole. In contrast to prior art modulators which usually position the rotor upstream of the stator, the rotor of the modulator 32 is located downstream of the stator.
  • both the stator 40 and the rotor 41 are provided with a plurality of radially extending lobes 71, 72 circumferentially spaced in a symmetrical fashion about coaxial central hubs.
  • the lobes constitute wedge-like projections radiating from the hub, each lobe being defined by a top (upstream surface), a base (downstream surface), opposite radially-extending sides (surfaces extending outwardly from the hub that join the top and the base), and an end (surface furthest from and concentric with the hub that abuts the inner walls of the housing).
  • All lobes 71 of the stator 40 are identically constructed and all lobes 72 of the rotor 41 are identically constructed.
  • the same number of lobes is used for the stator and the rotor, this number being conveniently selected as six. Selection of a different number is possible, but will change the characteristics of the generated signal.
  • stator 40 and rotor 41 may optionally be provided with a rim that circumscribes the ends of its lobes.
  • the stator 40 may also, alternatively, be formed integrally with the housing 42. This is a choice based on manufacturing convenience.
  • the ports between adjacent lobes on each of the stator and the rotor are defined by the periphery of the hub and the facing sides of adjacent lobes. It is considered advantageous, though not essential, for the respective lobes and intervening ports to be dimensioned so that they are approximately the same size.
  • the six lobes 71 of the stator 40 (Figs. 3a, 3b, 4a and 4b) are evenly distributed about the stator hub.
  • the tops and bases of the stator lobes 71 are parallel to each other and perpendicular to the hub axis.
  • the sides of the lobes 71 are generally radial with respect to the hub axis, with opposite sides of each lobe being angled at 30° and like sides of adjacent lobes being angled at 60° relative to the hub axis (Fig. 4a).
  • the internal threads 50 provided on the inside of the stator hub (see Fig.
  • Stator lobes 71 are formed with the outer width Wl and area of the top of the lobe being equal to the outer width W2 and area of the base of the lobe (Fig. 6).
  • Stator ports are formed to have equal inlet and outlet openings, with the inner and outer widths Pl, P3 of the inlet openings being the same as the respective inner and outer widths P2, P4 of the outlet openings.
  • the rotor lobes 72 (Figs. 3a, 3b and 5a-5c) are evenly distributed about the rotor hub so that radial lines drawn from the hub axis through centers of lobes 72 make angles of 60° with each other and angles of 30 0 with lines drawn from the hub axis through the centers of adjacent rotor ports (see Fig. 5a).
  • the lobes 72 of the rotor 41 Like those of the stator 40, the lobes 72 of the rotor 41 have parallel tops and bases which are perpendicular to the hub axis.
  • the sides of the lobes 72 are outwardly tapered in the direction of fluid flow ("positive" taper).
  • the outside width W4 (see Fig.
  • Fig. 5c illustrates a preferred positive uniform taper of 12° for the sides of the lobes 72. Other tapers of 8° to 30° are also suitable.
  • each rotor lobe 72 (formed where the sides meet the top) are angled at 27 0 , as are the edges 76 and 77 (formed where the sides meet the base).
  • the tops of the rotor lobes 72 underlap the bases of the stator lobes 71, with the outside width W3 (Fig. 6) and area of the top of each rotor lobe 72 being less than the corresponding outside width W2 and area of the base of each stator lobe 71.
  • the rotor ports are configured in a complementary way, so that the inside width P5, outside width P7 and area of the inlet opening of each rotor port are greater than the corresponding inside width P2, outside width P4 and area of the outlet opening of each stator port (see Fig. 6). Since the rotor ports are formed by the spaces between the rotor lobes 72, the sides of the ports are inwardly tapered in the downstream direction.
  • each rotor lobe 72 has a bore 80 to receive the machine screws 57 (Fig. 2) which serve to fasten the lobes 72 to the rotor bushing 59.
  • stator and rotor lobes 71, 72 causes the flowing mud to exert fluid dynamic forces on the rotor which bias the modulator 32 into a stable open position.
  • forces are generated that act on the geometry of the modulator to cause high pressure to be applied to one side of the rotor lobes 72 and low pressure to be applied to the other side. These forces urge the rotor lobes 72 into positions directly below the stator lobes 71, thereby aligning stator and rotor ports to provide the greatest passageway for flow of fluid through the modulator 32.
  • Example stator and rotor dimensions for a modulator, configured as shown in Figs. 3a-5c, that exhibits stable open performance are given below. These dimensions give an underlap between rotor and stator of 1/8" and gave satisfactory performance at a rotor-stator spacing of 1/16". Dimensions are identified with reference to Fig. 6.
  • modulator 32 will exhibit the stable closed performance of prior art devices.
  • modulator 32 will thus act in the manner of a check valve, opening in response to fluid flow in one direction and closing in response to fluid flow in the other direction.
  • stable open modulators 32 can be constructed following the same principles applied above.
  • stator should be located upstream of the rotor.
  • Stator lobes should preferably have straight (untapered) radially-extending sides and be dimensioned so that lobes and intervening ports have approximately the same size.
  • the rotor thickness (Fig. 6) should preferably be equal to or less than the thickness of the stator.
  • the sides of the rotor lobes should be outwardly tapered in the downstream direction, with a positive taper preferably of 8° to 30 0 .
  • Underlap should be provided between the top of the rotor lobes and the base of the stator lobes (i.e. the area of the top of the rotor lobes should be smaller than the area of the base of the stator lobes).
  • Rotor-stator spacing should not be too small. Suitable spacing can be determined empirically. Smaller spacings give stronger signals; larger spacings give better stable open performance. t
  • a second embodiment of the modulator 32 constructed in accordance with the foregoing criteria, comprises a stator 85 and a rotor 86 as illustrated in Figs. 7a and 7b.
  • the stator 85 has five lobes 87 evenly spaced about the periphery of a central stator hub.
  • Example stator and rotor dimensions for a stable open modulator, configured as shown in Figs. 7a and 7b for operation with a rotor-stator spacing of 3/32" are given below:
  • the rotor 86 is located downstream of the stator 85 and likewise has five lobes 88 evenly spaced about a central hub.
  • the sides of the lobes 88 are outwardly tapered in the downstream direction with a positive taper of 30°.
  • the outside width W3 of each rotor top is slightly greater than the outside width W2 of each stator lobe base (see end view Fig. 7b).
  • Underlap is provided between the stator lobes 87 and the rotor lobes 88 by providing a greater angle of convergence for the top edges of the sides of the rotor lobes 88 than for the bottom edges of the sides of the stator lobes 87. As shown in Fig.
  • the lower edges 89 of the sides of each rotor lobe 85 are angled at 52° and radiate outwardly from a point on the center axis of the rotor hub.
  • the upper edges 90 and 91 of the sides of each rotor lobe 86 also angled at 52 0 , radiate from a point along the lobe centerline displaced from the hub axis. Consequently, the rotor lobe top has a smaller surface area than that of the base of the stator lobe 85.
  • Fig. 8 illustrates another embodiment of the present invention that comprises a stator 100 positioned upstream of a rotor 101.
  • the stator 100 has six lobes and is similar to the stator 40, previously described with reference to Figs. 4a and 4b.
  • the sizes of the stator lobes 102 and intervening stator ports are the same, with the widths Wl, W2, P3 and P4 all being equal (see Fig. 6).
  • the rotor 101 is designed so that the outside width W4 of the base of each lobe 103 is equal to the outside width P8 of the outlet of each port.
  • stator port inlet and outlet openings and rotor port outlet openings have the same sizes, minimizes interference of the rotor taper with the fluid flow when the modulator is in its open position. This has the advantage of reduced wear and erosion of the rotor lobes 103.
  • rotor thickness can be reduced by milling the top of the rotor. This, however, reduces the underlap between the tops of the rotor lobes 103 and the bases of the stator lobes 102.
  • a region 104 of increased taper is provided by cuts made on an inside part (adjacent the rotor hub 105) of the upstream edges of the sides of the lobes 103. These partial cuts 104 assist the tapered sides to establish the fluid dynamic forces that provide the stable open characteristic of the modulator 32.
  • Fig. 9 shows a modification of the partial cut construction of the rotor 101 of Fig. 8.
  • the rotor 106 of Fig. 9 differs from the rotor 101 of Fig. 8 in that the outside widths W2, W4 and P4, P8 are not equal.
  • the sides of each rotor lobe 107 each have a positive taper of approximately 12° and each lobe 107 is provided with partial cuts 108 of increased taper similar to the cuts 104 of rotor 101.
  • a modulator 32 comprises a stator 110 and a rotor l13 mounted within a housing 42.
  • the stator 110 is like the six-lobed stator 40 previously described.
  • the sides of its lobes 111 are untapered and are generally radial with respect to the stator hub axis.
  • the sides of the lobes 111 of the rotor 113 also have leading and trailing untapered regions 115, 116 which are parallel to the sides of the stator lobes 111 (see unwrapped view of Fig. lOb.)
  • the outer width W3 (Fig. 6) of the top of the rotor lobe 114 that abuts the leading untapered region 115 is less than the outer width W2 of the base of the stator- lobe 111, thus providing underlap.
  • the outer width W4 of the base of the rotor lobe l14 that abuts the trailing untapered region 116 is approximately the same as the outer width W3 of the top.
  • the trailing untapered region 116 of each rotor lobe side is formed by undercutting the tapered region across the full depth of the rotor lobe 114.
  • the edges between the rotor lobe top and the leading regions 115 of the rotor lobe sides are preferably sharp in order to assert a cutting action on debris lodged in the gap between the stator and the rotor.
  • Figs. 10a and 10b generates fluid dynamic forces in response to the drilling fluid through direct impact and vortex separation that act on the rotor 113 to urge the modulator into a stable open position.
  • the restoring forces in the azimuthal direction are proportional to the angular displacement, with the result that a periodic motion in the nature of aerodynamic flutter is set up when the rotor is not driven by the shaft.
  • the amplitude and frequency of the flutter depend on the fluid flow rate, the modulator configuration and the shaft inertia. This flutter causes the rotor lobes 114 to oscillate between partially closed and fully open positions, also generating an acoustic signal whose frequency depends upon the flutter rate.
  • flutter rate is a function of flow rate
  • the modulator construction of Figs. 10a and lOb can be employed for flow rate monitoring, with the frequency of the generated signal being monitored in a known way, such as by conventional frequency analyzing circuitry incorporated into the signal detector 36 (Fig. 1).

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Geophysics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Remote Sensing (AREA)
  • Acoustics & Sound (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Hydraulic Motors (AREA)
  • Measurement Of Mechanical Vibrations Or Ultrasonic Waves (AREA)
  • Surgical Instruments (AREA)
  • Measuring Fluid Pressure (AREA)
EP84402124A 1983-10-24 1984-10-23 Druckimpulsgenerator Withdrawn EP0140788A3 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US54531383A 1983-10-24 1983-10-24
US545313 1990-06-27

Publications (2)

Publication Number Publication Date
EP0140788A2 true EP0140788A2 (de) 1985-05-08
EP0140788A3 EP0140788A3 (de) 1986-01-29

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Family Applications (1)

Application Number Title Priority Date Filing Date
EP84402124A Withdrawn EP0140788A3 (de) 1983-10-24 1984-10-23 Druckimpulsgenerator

Country Status (7)

Country Link
EP (1) EP0140788A3 (de)
AU (1) AU3459984A (de)
BR (1) BR8405278A (de)
CA (1) CA1228909A (de)
ES (1) ES537000A0 (de)
NO (1) NO844026L (de)
OA (1) OA07846A (de)

Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0448845A1 (de) * 1986-01-29 1991-10-02 Schlumberger Canada Limited System für Bohrlochmessungen während des Bohrens
EP0916807A3 (de) * 1997-11-18 2001-10-31 Anadrill International, S.A. Generator für Druckimpulse für ein Gerät zum Messen während des Bohrens zur Erregung von hohen Signalstärke und Verhütung des Festfressens
US6970398B2 (en) 2003-02-07 2005-11-29 Schlumberger Technology Corporation Pressure pulse generator for downhole tool
GB2415977A (en) * 2004-07-09 2006-01-11 Aps Technology Inc Rotary pulsar
WO2006041308A3 (en) * 2004-10-12 2006-06-15 Well Technology As System and method for wireless data transmission
US7330397B2 (en) 2005-01-27 2008-02-12 Schlumberger Technology Corporation Electromagnetic anti-jam telemetry tool
US9238965B2 (en) 2012-03-22 2016-01-19 Aps Technology, Inc. Rotary pulser and method for transmitting information to the surface from a drill string down hole in a well
US9540926B2 (en) 2015-02-23 2017-01-10 Aps Technology, Inc. Mud-pulse telemetry system including a pulser for transmitting information along a drill string
US10323511B2 (en) 2017-02-15 2019-06-18 Aps Technology, Inc. Dual rotor pulser for transmitting information in a drilling system
US10465506B2 (en) 2016-11-07 2019-11-05 Aps Technology, Inc. Mud-pulse telemetry system including a pulser for transmitting information along a drill string
US10577927B2 (en) 2015-10-21 2020-03-03 Halliburton Energy Services, Inc. Mud pulse telemetry tool comprising a low torque valve
US11499420B2 (en) 2019-12-18 2022-11-15 Baker Hughes Oilfield Operations Llc Oscillating shear valve for mud pulse telemetry and operation thereof
WO2023051610A1 (zh) * 2021-09-30 2023-04-06 中国石油化工股份有限公司 一种基于双向通讯的泥浆脉冲发生系统
US11753932B2 (en) 2020-06-02 2023-09-12 Baker Hughes Oilfield Operations Llc Angle-depending valve release unit for shear valve pulser

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EP3000961A1 (de) 2012-12-17 2016-03-30 Evolution Engineering Inc. Verfahren zum betreiben einer druckimpulstelemetrievorrichtung mit einem druckaufnehmer
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EP0448845A1 (de) * 1986-01-29 1991-10-02 Schlumberger Canada Limited System für Bohrlochmessungen während des Bohrens
EP0916807A3 (de) * 1997-11-18 2001-10-31 Anadrill International, S.A. Generator für Druckimpulse für ein Gerät zum Messen während des Bohrens zur Erregung von hohen Signalstärke und Verhütung des Festfressens
US6970398B2 (en) 2003-02-07 2005-11-29 Schlumberger Technology Corporation Pressure pulse generator for downhole tool
GB2415977B (en) * 2004-07-09 2009-06-17 Aps Technology Inc Improved rotary pulser for transmitting information to the surface from a drill string down hole in a well
GB2415977A (en) * 2004-07-09 2006-01-11 Aps Technology Inc Rotary pulsar
US7327634B2 (en) 2004-07-09 2008-02-05 Aps Technology, Inc. Rotary pulser for transmitting information to the surface from a drill string down hole in a well
US8169854B2 (en) 2004-10-12 2012-05-01 Well Technology As System and method for wireless data transmission
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US7330397B2 (en) 2005-01-27 2008-02-12 Schlumberger Technology Corporation Electromagnetic anti-jam telemetry tool
US9238965B2 (en) 2012-03-22 2016-01-19 Aps Technology, Inc. Rotary pulser and method for transmitting information to the surface from a drill string down hole in a well
US9540926B2 (en) 2015-02-23 2017-01-10 Aps Technology, Inc. Mud-pulse telemetry system including a pulser for transmitting information along a drill string
US10577927B2 (en) 2015-10-21 2020-03-03 Halliburton Energy Services, Inc. Mud pulse telemetry tool comprising a low torque valve
US10465506B2 (en) 2016-11-07 2019-11-05 Aps Technology, Inc. Mud-pulse telemetry system including a pulser for transmitting information along a drill string
US10323511B2 (en) 2017-02-15 2019-06-18 Aps Technology, Inc. Dual rotor pulser for transmitting information in a drilling system
US11499420B2 (en) 2019-12-18 2022-11-15 Baker Hughes Oilfield Operations Llc Oscillating shear valve for mud pulse telemetry and operation thereof
US11753932B2 (en) 2020-06-02 2023-09-12 Baker Hughes Oilfield Operations Llc Angle-depending valve release unit for shear valve pulser
WO2023051610A1 (zh) * 2021-09-30 2023-04-06 中国石油化工股份有限公司 一种基于双向通讯的泥浆脉冲发生系统
GB2626118A (en) * 2021-09-30 2024-07-10 China Petroleum & Chem Corp Mud pulse generation system based on two-way communication
US12366155B2 (en) 2021-09-30 2025-07-22 China Petroleum & Chemical Corporation Mud pulse generation system based on two-way communication

Also Published As

Publication number Publication date
EP0140788A3 (de) 1986-01-29
OA07846A (en) 1986-11-20
BR8405278A (pt) 1985-08-27
CA1228909A (en) 1987-11-03
ES8601384A1 (es) 1985-10-16
AU3459984A (en) 1985-05-09
ES537000A0 (es) 1985-10-16
NO844026L (no) 1985-04-25

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