U.S. patent number 3,792,428 [Application Number 05/272,819] was granted by the patent office on 1974-02-12 for method and apparatus for controlling the downhole acoustic transmitter of a logging-while-drilling system.
This patent grant is currently assigned to Mobil Oil Corporation. Invention is credited to John W. Harrell, James H. Sexton.
United States Patent |
3,792,428 |
Harrell , et al. |
February 12, 1974 |
METHOD AND APPARATUS FOR CONTROLLING THE DOWNHOLE ACOUSTIC
TRANSMITTER OF A LOGGING-WHILE-DRILLING SYSTEM
Abstract
A logging-while-drilling system utilizes the flow of drilling
fluid within a borehole as the transmission medium for telemetering
downhole logging measurements to the earth's surface. The hydraulic
power within the drilling fluid is converted to suitable power for
driving a downhole acoustic transmitter which produces an acoustic
wave within the drilling fluid which is modulated with the
information describing the downhole logging conditions. The power
available for driving the transmitter is applied to the transmitter
when it exceeds the minimum starting power requirement of the
transmitter and is continuously applied to the transmitter so long
as it does not, after starting the transmitter, drop below the
minimum operating power requirement of the transmitter.
Inventors: |
Harrell; John W. (Duncanville,
TX), Sexton; James H. (Duncanville, TX) |
Assignee: |
Mobil Oil Corporation (New
York, NY)
|
Family
ID: |
23041441 |
Appl.
No.: |
05/272,819 |
Filed: |
July 18, 1972 |
Current U.S.
Class: |
367/85; 322/32;
200/61.46; 361/241 |
Current CPC
Class: |
E21B
47/18 (20130101); E21B 3/00 (20130101); E21B
47/20 (20200501) |
Current International
Class: |
E21B
47/18 (20060101); E21B 47/12 (20060101); E21B
3/00 (20060101); G01v 001/40 () |
Field of
Search: |
;340/18NC,18 ;200/61.46
;322/12,32 ;317/5 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Wilbur; Maynard R.
Assistant Examiner: Moskowitz; N.
Attorney, Agent or Firm: Gaboriault; A. L. Hager, Jr.;
George W.
Claims
What is claimed is:
1. A logging-while-drilling tool comprising:
a. an elongated housing adapted for insertion into a borehole, and
through which drilling fluid is circulated during drilling
operation,
b. a rotary-driven member responsive to the hydraulic power in said
drilling fluid for generating mechanical power,
c. means for converting said mechanical power to electrical power,
said electrical power being of alternating current with a frequency
directly proportional to the speed of said rotary driven
member,
d. an acoustic transmitter, driven by said electrical power, said
acoustic transmitter periodically interrupting the flow of said
drilling fluid through said housing so as to produce a continuous
acoustic wave in the drilling fluid,
e. means for modulating said acoustic wave in response to a
measured downhole condition, the modulated acoustic wave passing
upward through the drilling fluid to the surface of the earth where
it is demodulated to provide a readout of the measured
condition,
f. means for converting the frequency of the alternating current of
said electrical power to an analog signal of amplitude proportional
to the frequency of said alternating current, such analog signal
thereby representing the speed of said rotary-driven member,
and
g. means responsive to said analog signal for providing a control
signal of a first state when said analog signal initially exceeds a
first voltage level representing the speed of said rotary-driven
member required for the generation of the required starting power
for said acoustic transmitter and of a second state when said
analog signal, after initially exceeding said first voltage level,
drops below a second voltage level representing the speed of said
rotary-driven member required for the generation of the required
operating power for maintaining continuous operation of said
acoustic transmitter, said second voltage level being lower than
said first voltage level.
2. The tool of claim 1 wherein said means for converting the
frequency of the alternating current of said electrical power to an
analog signal comprises:
a. means responsive to said alternating current for generating a
digital signal of fixed amplitude and pulse width, the period of
said digital signal being the same as the period of the frequency
of said alternating current, and
b. means for converting said digital signal to an analog signal
whose amplitude varies in accordance with the period of said
digital signal.
3. The tool of claim 1 wherein said means for providing said
control signal comprises:
a. a detector with input supplied by said analog signal, said
detector providing a digital output of a first logic level when the
amplitude of said analog signal has initially exceeded said first
voltage level and has not thereafter dropped below said second
voltage level and of a second logic level when the amplitude of
said analog signal has not initially exceeded said first voltage
level or has, after exceeding said first voltage level, thereafter
dropped below said second voltage level,
b. a switch coupled to said detector which is turned ON when the
digital output of said detector is at said first logic level and is
turned OFF when said digital output is at said second logic level,
and
c. means operable in response to the setting of said switch for
providing said control signal, said control signal enabling the
acoustic transmitter during the period when said switch is turned
ON.
4. The logging-while-drilling tool of claim 1 wherein said detector
comprises:
a. an amplifier to which said analog signal is applied, and
b. a gate having its input connected to the output of said
amplifier and having its output connected through a feedback path
to the input of said amplifier, whereby said gate is set to said
first logic level when said analog signal exceeds said first
voltage level and is maintained at said first logic level by means
of said feedback path until said analog signal drops below said
second voltage level.
Description
BACKGROUND OF THE INVENTION
This invention relates generally to the continuous logging of
downhole conditions within a borehole. More particularly, it
relates to logging while drilling wherein measurements of downhole
conditions within a borehole are telemetered to the surface of the
earth by means of a continuous acoustic wave passing upward through
the drilling fluid.
In the past, a conventional practice in the logging of a borehole
has been to apply electric current from a suitable source
aboveground through an insulated conductor extending into the
borehole to sensing apparatus. The sensing apparatus provides a
signal in the insulated conductor representative of the
characteristic measured within the borehole. The provision and
maintenance of such an insulated conductor for logging the borehole
while simultaneously drilling the borehole has been found to be
impractical.
More recently, logging-while-drilling systems have been employed
which do not require an insulated conductor in the borehole at any
time for logging operations. In one such system, the sensing
apparatus located within the borehole transmits the logging
measurements by means of an acoustic wave passing upward through
the drill string. An example of such a system is disclosed in U.S.
Pat. No. 2,810,546 to B. G. Eaton et al. In another such system the
drilling liquid within the borehole is utilized as the transmission
medium for the information-bearing acoustic waves. An example of
such a system is disclosed in U.S. Pat. No. 3,309,656 to John K.
Godbey. In the Godbey system, drilling fluid is continuously
circulated downward through the drill string and drill bit and
upward through the annulus provided by the drill string and the
borehole wall, primarily for the purpose of removing cuttings from
the borehole. An acoustic transmitter located downhole continuously
interrupts the flow of the drilling fluid, thereby generating an
acoustic wave in the drilling fluid. The acoustic wave is modulated
with information measured downhole by sensing apparatus, and the
modulated acoustic wave is telemetered uphole through the drilling
fluid to suitable recording equipment.
SUMMARY OF THE INVENTION
In accordance with one aspect of the invention the hydraulic power
in the drilling fluid which is being circulated through the
borehole is converted at a downhole location into electrical power.
This electrical power is utilized to generate a continuous acoustic
wave in the drilling fluid upon the electrical power exceeding a
first power level. The acoustic wave is maintained continuously so
long as the electrical power, after initially exceeding the first
power level, does not drop below a second power level. the acoustic
wave is modulated in response to a measured downhole condition, the
modulated acoustic wave passing upward through the drilling fluid
to the surface of the earth where it is demodulated to provide a
readout of the measured conditions.
In a further aspect, the electrical power drives an acoustic
transmitter which periodically interrupts the flow of drilling
fluid to produce the continuous acoustic wave. The electrical power
which is derived from the hydraulic power in the drilling fluid is
continuously monitored and is connected to the acoustic transmitter
only after it exceeds the starting power requirement of the
acoustic transmitter and is disconnected from the acoustic
transmitter when, after the transmitter is started, it drops below
the operating power required to maintain continuous operation of
the acoustic transmitter.
More particularly, a rotary-driven member is responsive to the
hydraulic power in the drilling fluid for generating mechanical
power. The mechanical power is converted into an
alternating-frequency electrical power, the frequency of the
electrical power being proportional to the speed of the
rotary-driven member and therefore proportional to the power
available for driving the acoustic transmitter. The frequency of
the electrical power is continuously detected. The electrical power
is connected to the acoustic transmitter to start-up the acoustic
transmitter when the detected frequency indicates that the speed of
the rotary-driven member exceeds the speed required to produce the
mechanical power sufficient for generating the electrical power
required to overcome the start-up load condition of the acoustic
transmitter. If, after start-up of the acoustic transmitter, the
detected frequency indicates that the speed of the rotary-driven
member has dropped below the speed required to produce sufficient
mechanical and electrical power to maintain continuous and
nonerratic operation of the acoustic transmitter, the electrical
power is disconnected from the acoustic transmitter to shut-down
the acoustic transmitter.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a cross-sectional view of a borehole logging tool
utilized in a logging-while-drilling system.
FIG. 2 is a flow diagram illustrating the components housed within
the borehole logging tool of FIG. 1.
FIG. 3 is a plot of the operating characteristics of one of the
components of FIG. 2.
FIG. 4 is a detailed electrical schematic of the transmitter
controller of the present invention.
FIG. 5 illustrates the waveforms of the signals appearing at the
designated points in the electrical schematic of FIG. 4.
DESCRIPTION OF THE PREFERRED EMBODIMENT
In accordance with the present invention a transmitter controller
is provided for controlling the start-up and shut-down of the
downhole acoustic transmitter in a logging-while-drilling system.
The transmitter controller turns the acoustic transmitter ON only
after the speed of the mud turbine has exceeded the minimum speed
required to generate maximum starting power for the acoustic
transmitter. Any time the turbine speed drops below the minimum
speed required to generate nominal operating power for the acoustic
transmitter, transmitter controller turns the acoustic transmitter
OFF. The transmitter controller of the present invention is
particularly suitable for inclusion in a logging-while-drilling
system utilizing conventional rotary drilling apparatus.
A brief description of a conventional rotary drilling apparatus
with which this invention can be used will be given prior to the
detailed description of the invention itself. In FIG. 1 there is
shown a downhole logging tool 10 formed by an inner housing 11
located within an outer housing 12. The inner and outer housings
define an annulus 13 through which drilling mud passes during
drilling operations. The upper and lower ends of the outer housing
12 are threaded for connection into a drill string. Within the
inner housing 11 are contained the operating parts of the
logging-while-drilling system, the power source, the modulation
section, the acoustic transmitter, and the transmitter
controller.
The power requirements for the acoustic transmitter are derived
from a power source comprising the mud turbine 15, the alternator
16, the voltage regulator 35, and the DC/AC inverter 36. The mud
turbine 15 is located immediately below the lower section 14, and
the alternator 16 is located within the lower section 14. During
the drilling operations, drilling fluid, preferably "mud," is
continuously circulated through the drill bit by a positive
displacement pump located aboveground, primarily to remove cuttings
from the hole. There is substantial hydraulic power in this
drilling mud. In the logging-while-drilling system, this drilling
mud is passed through the annulus 12, and the hydraulic power is
converted to mechanical power by means of the mud turbine 15. Mud
turbine 15 drives the alternator 16 to convert the mechanical power
to AC electrical power. Located within a middle section 17 is the
voltage regulator 35 which rectifies and filters the AC power
output from the alternator 16 and provides a regulated DC power
output. The DC/AC inverter 36 converts the DC power into suitable
AC power for starting and operating the acoustic transmitter. The
middle section 17 is sealed from the lower section 14 by means of
bulkhead 29. The electrical connection from the alternator 16 to
the voltage regulator 35 passes through this bulkhead.
Also located near and in communication with middle section 17 are
the various types of transducers used to convert such downhole
conditions as fluid pressures and temperatures, drilling conditions
and parameters, and formation characters into analog electrical
signals. These analog signals are applied to the modulation section
18 for conversion into digital signals for use in modulating the
acoustic transmitter. The collar 19 surrounding the outer housing
12 provides a compartment 20 within which the transducers may be
located. The transducers communicate with the modulation section 18
by means of the channel 21 leading from compartment 20 into the
middle section 17.
Located within an upper section 22 is an induction motor 23 and a
drive train 24. An acoustic generator comprising a fixed stator 25
qnd a rotary valve 26 is located immediately above the upper setion
22. These four components, induction motor 23, drive train 24,
stator 25, and rotary valve 26, comprise the acoustic transmitter.
Rotary motion of the rotary valve 26 is initiated and maintained by
the induction motor 23 which is connected rigidly to the rotating
valve through the drive train 24. The induction motor 23 is
electrically connected to the DC/AC inverter 36 through the
bulkhead 30 which seals the middle section 17 from the upper
section 22. The stator 25 and the rotary valve 26 have
complementing slots 27 and 28. The rotor is in an open position
when the slot 28 is rotated to a position which is in communication
with the slot 27 of the stator 25. In this open position, the
drilling mud will pass through the slots in the rotor and stator
and through the annulus 13 to drive the turbine 15. The hydraulic
power in the drilling mud is converted by the turbine 15 to
mechanical power which in turn is converted to electrical power for
rotating the rotary valve 26. As the valve 26 is rotated, it
continuously interrupts the flow of mud, thereby generating the
acoustic signal which travels upward through the mud column to the
surface of the earth.
This acoustic signal may be modulated with the digital signals
which represent the downhole condition measurements from the
transducers. These digital signals are utilized within the
modulation section 18 to control the frequency of the AC power
applied to the induction motor 23 and, consequently, the speed of
the induction motor 23. As it is the speed of the induction motor
which determines the frequency of the acoustic signal, the acoustic
signal is therefore frequency modulated in response to the digital
signals representing the downhole conditions measured by the
logging transducers. In this manner, modulated, continuous,
acoustic waves travel uphole in the drilling mud and are received
at the earth's surface and demodulated to provide a readout of the
downhole conditions.
Referring now to FIG. 2, there is illustrated in flow diagram the
details of the borehole logging tool illustrated in FIG. 1. As
previously described, the mud turbine 15 converts the hydraulic
power in the drilling mud to mechanical power for driving the
alternator 16 which, preferably, is a three-phase, six-pole
alternator. The three-phase, AC power from the alternator 16 is
applied to a voltage regulator 35 which rectifies and filters the
AC power output from the alternator and provides a regulated DC
voltage output. This regulated DC voltage is converted by a DC/AC
inverter 36 into suitable AC power for starting and operating the
induction motor 23 in the acoustic transmitter.
The downhole measurements of the transducers 34, in analog form,
are coded into binary digital words by an A/D converter 37. Each
digital word is converted into serial binary bits by an encoder 38
and applied to motor control 39 which in turn regulates the
frequency of the AC power applied from the DC/AC inverter 36 to the
induction motor 23, consequently varying the speed of the induction
motor 36 and thereby modulating the acoustic signal output from the
acoustic generator 27 in accordance with the digital information
applied to the motor control circuit 39.
An example of the type of borehole logging tool illustrated in FIG.
1 and discussed so far in relationship to FIG. 2 is set forth in
U.S. Pat. No. 3,309,656 to John K. Godbey. For a more detailed
description of the mechanical and electrical features of such a
borehole logging tool, reference may be had to the aforementioned
patent to Godbey. In addition to the circuitry illustrated and
described so far with relationship to FIG. 2, there is also
illustrated the transmitter controller portion 40 which comprises
the present invention. Transmitter controller 40 comprises a
turbine speed detector 41, a power detector 42, and electronic
switch 43, and an ON-OFF control 44. Prior to describing the
operation of the transmitter controller 40, there will be described
the operating characteristics of the mud turbine 15 utilized in the
logging-while-drilling system to which the operation of the
transmitter controller 40 is directed.
Such characteristics of the mud turbine are illustrated in FIG. 3
wherein turbine speed is plotted versus power output for constant
mud flow rates. Curves are shown for mud flow rates between 300 and
400 gallons per minute (gpm). These curves show the speed
regulation characteristics of the mud turbine 15 with load and flow
rate. The alternator 16/regulator 35 operating domain is shown
superimposed on the turbine characteristics as the enclosed area a,
b, c, d. As the AC power is initially applied to the acoustic
transmitter during transmitter start-up, a start-up load is
presented to the power source. This start-up load causes the mud
turbine speed to decrease. However, to maintain the maximum
regulated DC power output from the voltage regulator 35, the
turbine speed must always exceed some minimum requirement. For
purposes of example, the turbine speed should exceed 2500 rpm to
maintain the maximum DC power output. Below 2500 rpm, the
alternator 16 and the regulator 35 will provide regulated DC
voltage but at a power which is reduced due to the start-up load
conditions.
Positive displacement pumps are conventionally used on drilling
rigs to maintain the mud flow. The mud flow rate is therefore
fairly constant with constant pump rpm. The constant flow rate
curves in FIG. 3 are turbine load lines and characterize the
decrease in turbine speed with increase in load. For mud flow rates
below 300 gpm, all turbine load lines intersect line ab which
corresponds to the minimum input speed, 2500 rpm, to the alternator
16 and regulator 35 required for the generation of maximum
regulated DC power. If the electrical load which occurs during the
acoustic transmitter turn-on and which appears as a mechanical load
on the mud turbine 15 is sufficient to decrease the turbine speed
below 2500 rpm, then loss of maximum regulated DC power occurs and
adequate power may not be available to start the induction motor 23
of the acoustic transmitter. After the induction motor 23 is turned
ON, it requires the major portion of the available power. If during
the operation of the acoustic transmitter the turbine speed drops
below the minimum speed required to maintain maximum available
regulated DC power, then erratic acoustic transmitter operation
could result. To avoid these problems of starting and operating the
acoustic transmitter, the transmitter controller of the present
invention is provided to initiate acoustic transmitter turn-on at a
predetermined turbine speed sufficient to ensure that the turbine
operating point in FIG. 3 is on a load line which intersects line
bc. If the load line intersects line bc, maximum regulated DC power
is available from the regulator 35 for transmitter turn-on. For
example, assume that the predetermined speed has been set to 3400
rpm for transmitter turn-on. As the mud pumps are turned ON, the
mud flow rate increases and the mud turbine speed increases. As the
turbine speed exceeds 1800 rpm, regulated, but less than maximum,
DC power becomes available and all the electronic circuitry, except
the acoustic transmitter and the DC/AC inverter 36, automatically
turns ON. When the turbine speed attains 3400 rpm, the mud flow
rate is greater than 310 gpm. The exact flow rate depends on the
turbine load for the acoustic transmitter OFF condition power
demand. This power demand is generally low. All turbine
characteristic curves for flow rates above 310 gpm intersect line
bc. Therefore, maximum regulated DC power will be available for
transmitter start-up.
After the transmitter is turned ON, adequate regulated DC power
continues to be available so long as the turbine speed exceeds a
minimum value corresponding to the required power demand of the
entire logging-while-drilling system. To prevent erratic
transmitter operation due to loss of regulated DC power during
logging-while-drilling operations as discussed above, the
transmitter controller functions to turn OFF the acoustic
transmitter should the turbine speed drop below 2500 rpm, for
example. The transmitter remains OFF until the turbine speed
increases again to 3400 rpm.
The mud turbine speeds required to start-up and shutdown the
acoustic transmitter of 3400 rpm and 2500 rpm, respectively, are
used herein only as examples to aid in the understanding of the
operation of a conventional borehole logging tool of the type
disclosed, for example, in the aforementioned patent to Godbey. The
transmitter controller of the present invention may be designed to
operate with any operating speeds of the mud turbine for which
acoustic transmitter control is sought. The important consideration
in choosing the mud turbine speed at which the transmitter
controller is to be started is that the power generated at such
speed be sufficient to prevent the sudden load generated by the
acoustic transmitter upon start-up from causing the turbine speed
to drop below a speed necessary to maintain adequate starting
power.
Having now described both the mechanical and electrical features of
an example of a conventional logging-while-drilling system to which
the transmitter controller of the present invention may best be
directed, there will now be described in detail, in connection with
FIGS. 4 and 5, a preferred embodiment of the transmitter controller
of the present invention.
Referring now to FIG. 4, there is illustrated the detailed
schematic diagram of the transmitter controller of the present
invetnion comprising a turbine speed detector 41, a power detector
42, an electronic switch 43, and an ON-OFF control 44. Input to the
turbine speed detector 41 is supplied by one of the three outputs
of the three-phase alternator 16. The frequency of each of the
three-phase components of the input voltage is proportional to the
speed of the shaft of alternator 16 and, consequently, proportional
to the mud turbine speed. This relationship is as follows:
f = (P/2)(M/60) (1)
where,
f = frequency in Hz,
P = number of poles, and
M = speed of shaft in rpm.
This input is represented by the waveform V.sub.a in FIG. 5.
Turbine speed detector 41 comprises a monostable multivibrator
section 45 and a low-pass filter section 46. Monostable
multivibrator 45 is biased such that the collector voltage of the
output transistor 47 is at zero volts when the multivibrator is in
the OFF condition. Each time the input V.sub.a passes through zero
volts in the negative-going direction, transistor 49 is triggered
and the monostable multivibrator 45 provides a fixed amplitude and
fixed pulse width digital signal V.sub.b at the output of
transistor 47, the period of digital signal V.sub.b thereby being
the same as the period of the alternating current input V.sub.a.
Digital signal V.sub.b as illustrated in FIG. 5 varies between the
limits of b.sub.1 when the monostable multivibrator 45 is in the
OFF condition to a level of b.sub.2 when the monostable
multivibrator 45 is triggered. Upon triggering of monostable
multivibrator 45, the digital signal V.sub.b remains at the b.sub.2
level for a period in the order of one millisecond. Digital signal
V.sub.b is applied to the minus input of the operational amplifier
48 of the low-pass filter section 46. The low-pass filter section
46 generates an output signal V.sub.c which is a DC voltage with
amplitude proportional to the period of the digital signal V.sub.b.
Output signal V.sub.c thereby directly represents the mud turbine
speed as set forth in Equation (1) above and is therefore
proportional to the power available for starting and operating the
acoustic transmitter. A sample waveform for the output signal
V.sub.c is illustrated in FIG. 5. The level c.sub.1 represents the
voltage level at which the turbine speed reaches 2500 rpm, and the
level c.sub.2 represents the voltage level at which the turbine
speed reaches 3400 rpm.
The output signal V.sub.c from the low-pass filter section 46 of
the turbine speed detector 41 is applied as input to power detector
42. Power detector 42 comprises an inverting DC amplifier 50 and an
output gate 51. Gate 51 is a logic inverter which is set to a logic
0 when the output of transistor 52 of inverting DC amplifier 50 is
below the threshold voltage level required to set gate 51. When the
inverting amplifier 50 provides an output which exceeds the
threshold voltage level of gate 51, gate 51 is set to a logic 1.
These logic settings of gate 51 are illustrated in FIG. 5 as
waveform V.sub.d. When logging-while-drilling operations are
initiated and the mud turbine reaches the speed of 3400 rpm, the
input V.sub.c to transistor 52 reaches the voltage level C.sub.2
and transistor 52 provides an output which exceeds the threshold
voltage level required to set gate 51 to a logic 1. Gate 51 remains
in the logic 1 state until the mud turbine speed drops to the level
of 2500 rpm, at which time the input V.sub.c is at the level
C.sub.1 and gate 51 returns to the 0 logic state. It can be noted
in FIG. 4 that the output of gate 51 is fed back to the base input
of transistor 52 of the inverting amplifier 50. This feedback
maintains the collector voltage of transistor 52 at a level which
exceeds the threshold voltage level for setting the gate 51 until
such time as the mud turbine speed has dropped below 2500 rpm.
The electronic switch 43 is turned ON and OFF by the power detector
42. Electronic switch 43 comprises an input gate 53 and a
transistor stage 54. Upon mud turbine speed exceeding 3400 rpm and
output gate 51 of power detector being set to a logic 1 state, the
input gate 53 of electronic switch 43 is set to a logic 0. This
logic 0 state of input gate 53 biases transistor 53 to an OFF
condition, which is the ON state for the electronic switch 43,
thereby opening the line 55 leading to ON-OFF control section 44.
Line 55 remains open until such time as the mud turbine speed drops
below 2500 rpm, at which time input gate 53 is set to a logic 1,
thereby driving transistor 55 into a condition of saturation, which
is the OFF state for the electronic switch 43, and setting output
line 55 to ground potential. The logic state of input gate 53 is
represented by the waveform V.sub.e in FIG. 5.
ON-OFF control section 44 is controlled directly by the ON-OFF
state of electronic switch 43. Prior to the mud turbine speed
initially reaching 3400 rpm, electronic switch 43 is OFF and the
ground potential on line 55 disables the voltage regulator 56 of
ON-OFF control section 44. During this period of time, a control
signal V.sub.f of voltage regulator 56 is at a first state of zero
volts. This control signal applied, by way of line 57 directly to
the DC/AC inverter 36, disables the DC/AC inverter 36, thereby
preventing AC power from being applied to the induction motor 23 of
the acoustic transmitter. Upon the mud turbine speed reaching 3400
rpm, the electronic switch 43 is turned ON, opening the line 55 to
ON-OFF control section 44. This enables the voltage regulator 56 to
change the control signal V.sub.f to a second state at a voltage
level of f.sub.1. Transistor 58 is provided to increase the output
current-carrying capability. The voltage level f.sub.1 of control
signal V.sub.f when applied by way of line 57 to the DC/AC inverter
36 is sufficient to enable the DC/AC inverter 36 to apply the
required power to the induction motor 23 for starting the acoustic
transmitter. ON-OFF control section 44 maintains the control signal
V.sub.f at the level f.sub.1 so long as the electronic switch 43 is
in the ON state. Upon the mud turbine speed dropping below 2500
rpm, the electronic switch 43 is turned OFF, thereby disabling the
ON-OFF control section 44 whereby the control signal V.sub.f
returns to the first state of zero volt, the DC/AC inverter 36 is
disabled, and the induction motor of the acoustic transmitter is
shut down.
It is to be understood that the transmitter controller illustrated
in FIG. 4 is merely representative of one embodiment of the present
invention. In such embodiment, various types and values of circuit
components may be utilized. In accordance with the specific
embodiment illustrated in FIG. 4, the following TABLE I sets forth
specific types and values of the circuit components:
TABLE I
Reference Designation Description Transistors 47,49 2N2907 (Texas
Instruments) Transistors 52,54 2N2483 (Texas Instruments)
Transistors 58 2N4912 (Motorola) Operational Amplifier 48 MC1556G
(Motorola) Gates 51,53 1/2 CD4011D (RCA) Voltage Regulator 56
.mu.A723 (Fairchild) V.sub.G +15 volts DC V.sub.H -15 volts DC
V.sub.I +10 volts DC Diode 620 (Texas Instruments) Capacitor C1,3 1
.mu.f Capacitor C2 0.1 .mu.f Capacitor C4 500 pf Resistor 1 39 K
ohms 2 30 K ohms 3 4 K ohms 4 1 K ohms 5,7,9 10 K ohms 6 24.9 K
ohms 8 50 ohms 10 402 K ohms 11 499 K ohms 12,16 49.9 K ohms 13 301
K ohms 14 8.7 K ohms 15 5.1 K ohms 17 2 K ohms 18 1.5 K ohms 19 1
ohm
It is to be understood that the foregoing described embodiment of
the transmitter controller may be utilized with any rotary power
source and acoustic transmitter which are suitable for use in a
borehole logging tool of a logging-while-drilling system. The
detailed description of the generation of the power required to
operate the acoustic transmitter and the generation and modulation
of the acoustic waves represents the operation of one embodiment of
a borehole logging-while-drilling system suitable for control by
the transmitter controller of the present invention. The
transmitter controller may be utilized with various modifications
to both the power source and the acoustic transmitter without
departing from the scope and spirit of the invention. Also, various
modulation techniques such as, for example, amplitude modulation,
frequency shift keying, or phase shift keying may be utilized.
Similarly, various modifications to the disclosed embodiment of the
transmitter controller itself may become apparent to one skilled in
the art without departing from the scope and spirit of the
invention as hereinafter defined by the appended claims.
* * * * *