U.S. patent number 3,800,277 [Application Number 05/272,838] was granted by the patent office on 1974-03-26 for method and apparatus for surface-to-downhole communication.
This patent grant is currently assigned to Mobil Oil Corporation. Invention is credited to John W. Harrell, Bobbie J. Patton, James H. Sexton.
United States Patent |
3,800,277 |
Patton , et al. |
March 26, 1974 |
**Please see images for:
( Certificate of Correction ) ** |
METHOD AND APPARATUS FOR SURFACE-TO-DOWNHOLE COMMUNICATION
Abstract
Downhole operations within a well borehole are controlled by
utilization of various communication channels within the borehole.
The conditions within these communication channels are detected
downhole and are applied to downhole comparators. Whenever the
condition with a communication channel is changed by an operator on
the earth's surface so that it exceeds a reference value, the
comparator provides an output signal. A control gate selectively
combines the output signals from the comparators to provide control
signals for utilization in the control of the downhole
operations.
Inventors: |
Patton; Bobbie J. (Dallas,
TX), Sexton; James H. (Duncanville, TX), Harrell; John
W. (Duncanville, TX) |
Assignee: |
Mobil Oil Corporation (New
York, NY)
|
Family
ID: |
23041523 |
Appl.
No.: |
05/272,838 |
Filed: |
July 18, 1972 |
Current U.S.
Class: |
367/83; 166/66;
175/26; 327/50; 175/24; 175/48; 73/152.03; 73/152.48; 73/152.43;
73/152.21 |
Current CPC
Class: |
E21B
47/20 (20200501); E21B 44/00 (20130101); G01V
3/34 (20130101); E21B 47/18 (20130101) |
Current International
Class: |
E21B
47/18 (20060101); E21B 47/12 (20060101); G01V
3/34 (20060101); E21B 44/00 (20060101); G01V
3/18 (20060101); G01v 001/40 (); E21b 041/00 () |
Field of
Search: |
;340/18LD,18R,421,222
;175/25,27,38,48,50,24 ;166/66 ;73/152 ;328/148,146 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Wilbur; Maynard R.
Assistant Examiner: Birmiel; H. A.
Attorney, Agent or Firm: Gaboriault; A. L. Hager, Jr.;
George W.
Claims
What is claimed is:
1. A method of controlling downhole operations in a
logging-while-drilling system including a drill bit connected to a
drill string through which a drilling fluid is circulated,
comprising:
a. selecting from the surface of the earth the conditions of each
of a plurality of operating parameters of the system,
b. measuring the conditions of each of said plurality of operating
parameters at a downhole location and producing a plurality of
output signals representing the conditions of said operating
parameters,
c. producing at said downhole location a plurality of reference
signals, at least one reference signal being produced for each of
said operating parameters,
d. comparing said output signals with their corresponding reference
signals,
e. producing first comparison signals of a first state when said
output signals exceed the reference signals to which they are
compared in step (d) and of a second state when said output signals
do not exceed the reference signals to which they are compared in
step (d),
f. gating selective combinations of said first comparison signals
to produce a plurality of control signals when each comparison
signal of a selected combination is of a required state, each said
control signal being thereby produced in response to a plurality of
the conditions selected in step (a) for each of said operating
parameters, and
g. utilizing said control signals to control downhole
operations.
2. The method of claim 1 further comprising:
a. producing a time integral for at least one of said output
signals,
b. comparing said time integral with the reference signal
corresponding to the operating parameter represented by said one of
said output signals,
c. producing second comparison signals of a first state when said
time integral exceeds the reference signal to which it is compared
in step (b) and of a second state when the time integral does not
exceed the reference signal to which it is compared in step (b),
and
d. gating selective combinations of said first and second
comparison signals to produce a plurality of control signals when
said comparison signals of a selected combination are all of a
required state, said control signals being thereby produced in
response to both the conditions selected in step (a) for each of
said operating parameters and the time periods during which said
operating parameters remain in the selected conditions.
3. The method of claim 1 wherein one of the operating parameters,
the condition of which is selectively controlled in step (a), is
the weight of the drill bit.
4. The method of claim 1 wherein one of the operating parameters,
the condition of which is selectively controlled in step (a), is
the rotary speed of the drill string.
5. The method of claim 1 wherein one of the operating parameters,
the condition of which is selectively controlled in step (a), is
the flow rate of the drilling fluid.
6. A system for controlling, from the surface of the earth, a
plurality of downhole operations in a drilling system,
comprising:
a. a plurality of means located on the surface of the earth for
controlling each of a plurality of the operating parameters of the
drilling system,
b. a plurality of subsurface means for detecting the conditions of
said plurality of operating parameters, and for producing output
signals representative of said conditions,
c. a plurality of subsurface means for producing a plurality of
reference signals, at least one reference signal corresponding to
each of said output signals,
d. a plurality of subsurface means for comparing said output
signals with their corresponding reference signals and for
producing comparison signals of a first state when the output
signals exceed their corresponding reference signals and of a
second state when the output signals do not exceed their
corresponding reference signals, and
e. subsurface means for selectively gating combinations of said
comparison signals to provide for a plurality of control signals to
be utilized in the control of downhole operations of the drilling
system, whereby any one of said control signals may be produced by
selectively controlling from the surface of the earth the
conditions of the operating parameters of the drilling system such
that each resulting comparison signal of a selected combination of
comparison signals is of the required state to produce a control
signal.
7. The system of claim 6 further including at least one integrator
to which at least one of said output signals and its corresponding
reference signal are applied, said integrator providing a time
integral signal of a first state when the integral of said one of
said output signals exceeds its corresponding reference signal for
a predetermined time interval and of a second state when the
integral of said one of said output signals does not exceed the
reference signal for a predetermined time interval, said time
integral signal being selectively applied to said plurality of
gates along with said comparison signals, whereby said control
signals may be produced by selectively controlling from the surface
of the earth both the conditions of the operating parameters of the
drilling system and the time periods during which said operating
parameters remain in the selected conditions.
8. In a logging-while-drilling system employing a drill bit
connected to a rotary drill string through which a drilling fluid
is circulated by means of a surface pump, a plurality of downhole
transducers for measuring the conditions of the operating
parameters, and an acoustic transmitter for telemetering the
information from the downhole location to the surface of the earth,
the combination comprising:
a. means located on the earth's surface for selecting the
conditions of the operating parameters of the
logging-while-drilling system, said plurality of transducers
producing output signals indicative of the selected conditions of
each of said operating parameters,
b. means located downhole for producing a plurality of reference
signals, at least one reference signal being produced for each of
said operating parameters,
c. a plurality of first downhole comparators which compare said
output signals with the corresponding reference signals and provide
a plurality of first comparison signals, said first comparison
signals being of a first state when the output signals exceed the
corresponding reference signal and of a second state when the
output signals do not exceed the corresponding reference signals,
and
d. a plurality of gates to which said first comparison signals are
selectively connected, said gates providing control signals each in
accordance with the states of the selected combinations of the
first comparison signals to which they are connected, said control
signals being thereby provided to control various downhole
operations of the logging-while-drilling system by selecting from
the surface of the earth the conditions of the operating
parameters.
9. The system of claim 8 further including:
a. means for producing time integrals of said output signals,
b. a plurality of second downhole comparators which compare said
time integrals with the corresponding reference signals and for
producing second comparison signals of a first state when said time
integrals exceed said reference signals and of a second state when
said time integral does not exceed said reference signals, and
c. a plurality of gates to which said second comparison signals are
selectively connected for providing control signals in accordance
with the states of the selected combinations of said second
comparison signals, whereby said control signals are selectively
produced by controlling from the surface of the earth the time
periods during which said operating parameters remain in the
selected conditions.
10. The system of claim 8 wherein at least one of said control
signals is utilized to control operation of the downhole acoustic
transmitter.
11. The system of claim 8 wherein at least one of said control
signals is utilized to control the calibration of downhole
equipment.
12. The system of claim 8 wherein at least one of said control
signals is utilized to control the data rate of the information
representing the measured downhole conditions and which is
telemetered uphole by means of the acoustic transmitter.
13. The system of claim 8 wherein at least one of said control
signals is utilized to control the sequence in which the measured
downhole conditions are telemetered uphole by means of the acoustic
transmitter.
14. The system of claim 8 wherein one of the operating parameters
is the weight on the drill bit.
15. The system of claim 8 wherein one of the operating parameters
is the rotary speed of the drill string.
16. The system of claim 8 wherein one of the operating parameters
is the flow rate of the drilling fluid.
Description
BACKGROUND OF THE INVENTION
This invention relates generally to logging while drilling wherein
control of downhole operations within a borehole are effected from
the surface of the earth. More particularly, control signals are
telemetered to a downhole tool by means of the communication
channels afforded by the various operating parameters.
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.
In order to control the downhole drilling and logging operations,
it has long been the practice to stop the operations and remove the
drill string from the well for the purpose of changing or switching
from one type of operation to another. The advantages of being able
to control and change such downhole operations from the surface of
the earth without stopping the operations and removing the drill
string from the borehole are obvious.
SUMMARY OF THE INVENTION
In accordance with one aspect of the invention, downhole
operations, that is, operations at any point along the length of
the borehole, are carried out by controlling various conditions
within the logging-while-drilling system. Changes in these
conditions are initiated at the surface of the earth and are
detected at a downhole location within the borehole. Output
signals, produced downhole in response to these changes, are
selectively combined to provide for a plurality of control signals
which are utilized to control the downhole operations.
In another aspect, the output signals are of a first state when the
absolute value of the condition within the communication channel
exceeds a reference value and of a second state when the absolute
value of the condition within the communication channel does not
exceed the reference value.
In a further aspect, the output signals are of a first state when
the time integral of the condition within the communication channel
exceeds a reference value and of a second state when the time
integral of the condition within the communication channel does not
exceed the reference value.
More particularly, at least one reference signal is provided for
each of the communication channels. Output signals will be produced
based upon the comparison of the condition within the communication
channel or its time integral with the corresponding reference
signal, the output signals for each communication channel being
equal in number to the number of reference values provided for each
communication channel. These output signals are selectively
connected to a plurality of gates which provide the plurality of
control signals in accordance with the logic states of the selected
output signals to which they are connected.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 illustrates a well drilling system adapted to simultaneously
drill and log a well.
FIG. 2 is a cross-sectional view of a borehole logging tool
utilized in a logging-while-drilling system.
FIG. 3 is a block diagram illustrating the components housed within
the borehole logging tool of FIG. 1.
FIG. 4 is a block diagram illustrating the communication control
system of the present invention.
FIGS. 5-7 and 10 are detailed electrical schematics of the
components of the communication control system of FIG. 4.
FIGS. 8 and 9 illustrate the waveforms of the signals appearing at
the designated points in the electrical schematics of FIGS. 5 and
6.
DESCRIPTION OF THE PREFERRED EMBODIMENT
In accordance with the present invention a communication control
system is provided for controlling the downhole operations at any
point along the length of the borehole in a logging-while-drilling
system. Signals are telemetered to a downhole tool by means of
communication channels which can be controlled either automatically
or by an operator from the surface of the earth. Such signals are
detected downhole and utilized to provide the necessary control for
the downhole operations.
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 derrick 20 located over a well 21 being drilled in the
earth by rotary drilling. A drill string 22 is suspended within the
well 21 from the derrick 20. The drill string 22 includes a
plurality of sections of drill pipe with one or more drill collars
and a drill bit 23 secured at its lower end and a kelly 24 secured
at its upper end. Kelly 24 extends through and is rotatably engaged
by rotary table 25. A suitable prime mover (not shown) drives a
member 26 which rotatably engages the rotary table 25, thereby
rotating the drill string 22 within the well 21. The member 26 is
superimposed directly above the wellhead 27. The wellhead 27 is
secured to a casing 28 which is cemented into position a short
distance into the well 21. A hook 29 is connected to the kelly 24
through a rotary swivel 30. Hook 29 is attached to a traveling
block (not shown) which in turn is suspended by a suitable cable
(also not shown). The rotary swivel permits rotation of the drill
string relative to the hook and traveling block. The swivel 30 also
forms a fluid connection between a source of drilling fluid, such
as mud, and the drill string 22. A pump 31 transfers the drilling
fluid from a pit 32 in the earth through a desurger 33, which is
adapted to suppress noise in the drilling fluid, and a flexible
hose 34 into the swivel 30. The drilling fluid then flows
downwardly into the drill string 22 and exits through openings in
the drill bit 23 into the well 21. The drilling fluid then
circulates upwardly from the drill bit 23 carrying formation
cuttings through the annulus between the drill string 22 and the
well 21 to the surface of the earth. A pipe 35 is connected to the
casing 28 for returning the drilling fluid from the well 21 to the
pit 32.
Located within the drill string 21 near the drill bit is a downhole
logging tool 40 which includes one or more transducers for
measuring downhole conditions and an acoustic transmitter which
produces an acoustic signal in the drilling fluid representative of
the downhole conditions. This acoustic signal is telemetered uphole
through the drilling fluid where it is received by one or more
transducers 41 mounted on the swivel 30. The signals from
transducers 41 are applied to a recording system 42 which provides
readout functions representative of the measured downhole
conditions.
The downhole logging tool 40 is illustrated in detail in FIG. 2.
The downhole logging tool 40 is formed by an inner housing 42
located within an outer housing 43. The inner and outer housings
define an annulus 44 through which drilling mud passes during
drilling operations. The upper and lower ends of the outer housing
43 are threaded for connection into a drill string. Within the
inner housing 42 are contained the operating parts of the
logging-while-drilling system, the power source, the modulation
section, the acoustic transmitter, and the communication control
section.
The power requirements for the acoustic transmitter are derived
from a power source comprising the mud turbine 50, the alternator
51, the voltage regulator 52, and the DC/AC inverter 53. The mud
turbine 50 is located immediately below the lower section 54 and
the alternator 51 is located within the lower section 54. 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 and prevent blowout. There is substantial hydraulic
power in this drilling mud. In the logging-while-drilling system,
this drilling mud is passed through the annulus 44, and the
hydraulic power is converted to mechanical power by means of the
mud turbine 50. Mud turbine 50 drives the alternator 51 to convert
the mechanical power to AC electrical power. Located within a
middle section 55 is the voltage regulator 52 which rectifies and
filters the AC power output from the alternator 51 and provides a
regulated DC power output. The DC/AC inverter 53 converts the DC
power into suitable AC power for starting and operating the
acoustic transmitter. The middle section 55 is sealed from the
lower section 54 by means of bulkhead 56. The electrical connection
from the alternator 51 to the voltage regulator 52 passes through
this bulkhead.
Located near and in communication with middle section 55 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
57 for conversion into digital signals for use in modulating the
acoustic transmitter. The collar 58 surrounding the outer housing
43 provides a compartment 59 within which the transducers may be
located. The transducers communicate with the modulation section 57
by means of the channel 60 leading from compartment 59 into the
middle section 55.
Also located within the middle section 55 is the communication
control section 61 which will be described in detail
hereinafter.
Located within an upper section 65 is an induction motor 66 and a
drive train 67. An acoustic generator comprising a fixed stator 68
and a rotary valve 69 is located immediately above the upper
section 65. These four components, induction motor 66, drive train
67, stator 68, and rotary valve 69, comprise the acoustic
transmitter. Rotary motion of the rotary valve 69 is initiated and
maintained by the induction motor 66 which is connected rigidly to
the rotating valve through the drive train 67. The induction motor
66 is electrically connected to the DC/AC inverter 53 through the
bulkhead 70 which seals the middle section 55 from the upper
section 65. The stator 68 and the rotary valve 69 have
complementing slots 71 and 72. The rotor is in an open position
when the slot 72 is rotated to a position which is in communication
with the slot 71 of the stator 68. In this open position, the
drilling mud will pass through the slots in the rotor and stator
and through the annulus 44 to drive the turbine 50. The hydraulic
power in the drilling mud is converted by the turbine 50 to
mechanical power which in turn is converted to electrical power for
rotating the rotary valve 69. As the valve 69 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 57 to control the frequency of the AC power
applied to the induction motor 66 and, consequently, the speed of
the induction motor. 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. 3 there are illustrated in flow diagram the
details of the borehole logging tool illustrated in FIG. 2. As
previously described, the mud turbine 50 converts the hydraulic
power in the drilling mud to mechanical power for driving the
alternator 51 which, preferably, is a three-phase, six-pole
alternator. The three-phase, AC power from the alternator 51 is
applied to a voltage regulator 52 which rectifies and filters the
AC power output from the alternator 51 and provides a regulated DC
voltage output. This regulated DC voltage is converted by a DC/AC
inverter 53 into suitable AC power for starting and operating the
induction motor 66 in the acoustic transmitter.
The downhole measurements of the transducers 76, in analog form,
are multiplexed by multiplexers 77 and are coded into binary
digital words by an A/D converter 73. Each digital word is
converted into serial binary bits by an encoder 74 and applied to
motor control 75 which in turn regulates the frequency of the AC
power applied from the DC/AC inverter 53 to the induction motor 66,
consequently varying the speed of the induction motor 66 and
thereby modulating the acoustic signal output from the acoustic
generator 78 in accordance with the digital information applied to
the motor control circuit 75.
An example of the type of borehole logging tool illustrated in FIG.
2 and discussed so far in relationship to FIG. 3 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.
Having now described both the mechanical and electrical features of
an example of a conventional logging-while-drilling system to which
the communication control of the present invention may be best
directed, there will now be described in detail, in connection with
FIGS. 4-9, a preferred embodiment of the communication control of
the present invention.
Referring now to FIG. 4, there is illustrated a block diagram of
the communication control of the present invention comprising a mud
flow rate detector 80 and a mud flow rate comparator 81, a
weight-on-drill-bit detector 81 and a weight-on-drill-bit
comparator 83, a drill string rotary speed detector 84 and a drill
string rotary speed comparator 85, and a control gate 86.
The flow rate of the drilling fluid, preferably, mud, through the
drill string is controlled from the pump 31 on the surface of the
earth. This flow rate may be utilized as one of the communication
channels from the surface of the earth to the downhole equipment.
The mud flow rate detector 80 provides an electrical signal MFR
which is proportional to the flow rate of the drilling mud, and
such MFR signal is applied to mud flow rate comparator 81. Mud flow
rate comparator 81 provides, for example, two output signals. The
first output signal is present whenever the mud flow rate is equal
to or exceeds the rate of 200 gallons per minute. The second output
signal is present whenever the mud flow rate is equal to or exceeds
a flow rate of 300 gallons per minute.
A weight-on-drill-bit detector 82 provides a WOB signal which is
proportional to the weight on the drill bit. This weight is
controllable by means of the hook 29 and its associated traveling
block (not shown). The WOB signal is applied to weight-on-drill-bit
comparator 83 which may, for example, provide two output signals.
The first output signal is present whenever the weight on the drill
bit is less than 1,000 pounds. The second output signal is present
whenever the weight on the drill bit is equal to or greater than
10,000 pounds.
The drill string rotary speed detector 84 provides an RS signal
which is proportional to the rotary speed of the drill string. The
rotary speed of the drill string is directly controllable by means
of the prime mover which drives the member 26 which in turn
rotatably engages the rotary table 25 for rotating the drill string
22. The RS signal is applied to drill string rotary speed
comparator 85 which, for example, may provide two output signals.
The first output signal will be present whenever the rotary speed
is less than five revolutions per minute. The second output signal
will be present whenever the rotary speed exceeds 50 revolutions
per minute but is less than 100 revolutions per minute.
Each of the output signals from the three comparators 81, 83, and
85 is applied to a control gate 86. Control gate 86 selectively
combines these signals to provide for a plurality of control
signals represented by the legends A-E.
It can be appreciated that the mud flow rate comparator 81, for
example, may be designed to provide for any number of outputs
depending upon the number of mud flow rate levels for which an
output signal is desirable, the two output signals for flow rates
of 200 gallons per minute and 300 gallons per minute merely being
used as examples. Similarly, the weight-on-bit comparator 83 and
the drill string rotary speed comparator 85 may each be designed to
provide for any number of output signals based upon the number of
levels of weight on bit and rotary speed for which output signals
are desirable.
In like fashion, the control gate 86 may be designed to combine the
output signals from the comparators in various selective
combinations to provide the desirable control signals, the control
signals A-E being illustrative of five such control signals.
It can therefore be seen that the three communication channels
illustrated in FIG. 4, that is, mud flow rate, weight on drill bit,
and rotary speed of the drill string, may be utilized to provide
for a plurality of control signals at a downhole location for
controlling the operation of the downhole equipment.
There is illustrated in FIG. 5 the detailed schematic diagram of a
mud flow rate detector 80. Input to the mud flow rate detector 80
is supplied by one of the three outputs of the three-phase
alternator 51. The frequency of each of the three-phase components
of the input voltage is proportional to the speed of the shaft of
alternator 51 and, consequently, proportional to the speed of the
mud turbine 50. 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. 8.
Mud flow rate detector 80 comprises a monostable multivibrator
section 100 and a low-pass filter section 101. Monostable
multivibrator 100 is biased such that the collector voltage of the
output transistor 102 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 103 is triggered
and the monostable multivibrator 100 provides a fixed amplitude and
fixed pulse width digital signal V.sub.b at the output of
transistor 102, 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. 8, varies between
the limits of b.sub.1 when the monostable multivibrator 100 is in
the OFF condition to a level of b.sub.2 when the monostable
multivibrator 100 is triggered. Upon triggering of monostable
multivibrator 100, 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 inverting
amplifier 104 of the low-pass filter section 101. The low-pass
filter section 101 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. 8. The level c.sub.1
represents the voltage level at which the turbine reaches a speed
representative of a mud flow rate of, for example, 200 gallons per
minute, and the level c.sub.2 represents the voltage level at which
the turbine reaches a speed representative of a mud flow rate of,
for example, 300 gallons per minute. This output signal V.sub.c
from the low-pass filter section 101 is applied by way of the
inverting amplifier 105 as the MFR signal to the mud flow rate
comparator 81.
The weight-on-drill-bit detector 82 provides the WOB signal which
is proportional to the weight on the drill bit. This weight is
controlled from the earth's surface by raising and lowering the
hook 29 by means of the associated traveling block (not shown).
As the weight on the drill bit is increased and decreased there are
corresponding increases and decreases in strain in the outer
housing 43 of the downhole logging tool 40. Such strain may be
measured by conventional strain gauges mounted on the outer housing
43 within the compartment 59 formed by the collar 58. The gauges
are mounted such that their sensitive axes are along the axis of
the borehole tool. These strain gauges communicate with the
communication control circuitry 61 within the middle section 55 by
means of the channel 60.
There is illustrated in FIG. 10 the detailed schematic of the
weight-on-drill-bit detector 82. Two strain gauges 190 and 191 form
two opposite legs of a conventional resistive bridge 194. These two
strain gauges are mounted on opposite sides of the outer surface of
housing 43 within the compartment 59, that is, 180.degree. removed
from each other about the housing 43. The two remaining legs of the
bridge 194 are formed by resistors 192 and 193. The resistors 192
and 193 are chosen so that the bridge 194 is balanced when the
strain gauges 190 and 191 are under a no-load or no-stress
condition. That is, the voltage V.sub.s across the output of the
bridge 194 is zero when the weight on the drill bit is zero.
As the weight on the drill bit is increased, there is an increase
in compression in the outer housing 43. The resistance of the
strain gauges 190 and 191 changes proportionately with this
increase in compression, thereby producing the voltage V.sub.s
across the output terminals of the bridge 194. The voltage V.sub.s
is amplified by the inverting amplifier 195 to provide for the WOB
signal which is directly proportional to the weight on the drill
bit.
Such strain gauges 190 and 191 are state of the art components. A
particularly suitable strain gauge is of the foil type in which a
thin film of metal is deposited on an insulator. Other types of
strain gauges such as wire and semiconductor gauges may also be
utilized.
The drill string rotary speed detector 84 provides the RS signal
which is proportional to the rotary speed of the drill string. This
speed is controlled from the earth's surface by means of a prime
mover (not shown) which drives the drill string through the rotary
table 25 and the member 26. Such a means for detecting the rotary
speed of the drill string is disclosed in U.S. Pat. No. 3,400,327
to James H. Sexton and Bobbie J. Patton.
The actual conditions of the three communication channels, mud flow
rate, weight on drill bit, and drilling string rotary speed, are
represented by the three signsls MFR, WOB, and RS. Other
communication channels may be utilized also, but these three are
used for illustrative purposes. The three signals MFR, WOB, and RS
are then applied, respectively, to comparators 81, 83, and 85. Each
of these comparators is illustrated in detail in FIG. 6. The
weight-on-drill-bit comparator 83 has the WOB signal applied to the
negative input of a unity gain inverting amplifier 110 which serves
the function of changing the WOB signal from a positive level to a
negative level. The output of amplifier 110 is coupled by way of
resistors 111 and 112 to the negative input terminals of inverting
amplifiers 113 and 114, respectively. A reference voltage V.sub.R
is applied by way of resistors 115 and 116 to the same negative
input terminals of amplifiers 113 and 114, respectively. This
reference voltage Vhd R is a positive voltage. Therefore, initially
when there is no weight on the drill bit, the WOB signal is zero
and a positive voltage is therefore applied by way of the voltage
divider comprising resistors 111 and 115 to the negative input
terminal of amplifier 113. This sets amplifier 113 to a logic "0"
state. As weight is applied to the drill bit, the WOB signal
increases in value, thereby causing the voltage level at the output
of amplifier 110 to go negative, thereby decreasing the value of
the positive input voltage to the negative input terminal of
amplifier 113. The resistors 111 and 115 in the voltage divider are
sized such that as the weight on the drill bit exceeds 1,000
pounds, the voltage applied to the negative input terminal of
amplifier 113 becomes negative. At this point the inverting
amplifier is switched to a logic "1" state. The output of inverting
amplifier 113 is applied by way of inverter 117 to output line 152.
As illustrated in FIG. 9 by the waveform WOB<1 KLB, a logic "1"
signal appears on output line 152 whenever the weight on the drill
bit is less than 1,000 pounds and a logic "0" signal appears on
output line 152 whenever the weight on drill bit is greater than
1,000 pounds.
In similar fashion to the operation of amplifier 113, the voltage
divider resistors 112 and 116 are sized such that amplifier 114 is
set to a logic "0" state so long as the weight on the drill bit is
less than 10,000 pounds. As the weight on the drill bit exceeds
10,000 pounds, the amplifier 14 is switched to th logic "1" state.
Therefore, a logic "0" signal appears on output line 153 from
comparator 83 whenever the weight on the drill bit is less than
10,000 pounds and a logic "1" signal appears whenever the weight on
the drill bit is greater than 10,000 pounds. This is illustrated in
FIG. 9 by the waveform WOB>10 KLB.
Mud flow rate comparator 81 is similar both in construction and
operation to weight-on-drill-bit comparator 83. The reference
voltage V.sub.R is again a positive-level voltage and the voltage
divider formed by resistors 120 and 121 is such that the amplifier
122 is set to a logic "0" signal when the MFR signal indicates that
the mud flow rate is less than 200 gallons per minute. When the mud
flow rate exceeds 200 gallons per minute, the MFR signal increases
negatively to such a level that the negative input terminal to
amplifier 122 is supplied with a negative voltage, thereby
switching amplifier 122 to a logic "1" state. Therefore, a logic
"1" signal appears on output line 151 whenever the mud flow rate is
greater than 200 gallons per minute.
In similar fashion, the voltage divider comprising resistors 123
and 124 is such that the amplifier 125 is set to a logic "0" state
when the mud flow rate is less than 300 gallons per minute. When
the mud flow rate exceeds 300 gallons per minute, the MFR signal
increases to a negative level such that the voltage divider
comprising resistors 123 and 124 provides a negative signal to the
negative input terminal of amplifier 125, thereby switching it to a
logic "1" state. Therefore, a logic "1" signal appears on line 150
whenever the mud flow rate exceeds 300 gallons per minute.
The drill string rotary speed comparator 85 is coupled at its input
to the RS signal which increases in a negative direction as the
rotary speed of the drill string increases. The reference voltage
V.sub.R is again a positive-level voltage and the voltage divider
resistors 130 and 131 are chosen such that so long as the rotary
speed of the drill string is less than 5 RPM the RS signal is of
such a level that the input to the amplifier 132 is a positive
voltage, thereby setting amplifier 132 to a logic "0" state. As the
rotary speed exceeds 5 RPM, the RS signal increases in the negative
direction to such an extent that the voltage divider comprising
resistors 130 and 131 applied a negative voltage to the negative
input terminal of amplifier 132, thereby switching it to a logic
"1" state. The output of amplifier 132 is applied by way of
inverter 133 to output line 154. Therefore, a logic "1" signal
appears on output line 154 whenever the rotary speed is less than 5
RPM.
Resistors 134 and 135 form a second voltage divider to which the RS
signal and the reference voltage signal are applied. Whenever the
RS signal is indicative of a rotary speed less than 50 RPM, a
positive voltage is applied to the negative input terminal of
amplifier 136, setting it to a logic "0" state. When the rotary
speed exceeds 50 RPM, the RS signal increases negatively to such an
extent that a negative voltage is applied to the negative input
terminal of amplifier 136, thereby setting it to a logic "1" state.
Resistors 137 and 138 form a third voltage divider to which the RS
signal and the reference signal V.sub.R are applied. So long as the
rotary speed is less than 100 RPM, the RS signal is of such a level
that a positive voltage is applied to the negative input terminal
of amplifier 139, thereby setting it to a logic "0" state. When the
rotary speed exceeds 100 RPM, the RS signal increases negatively to
such an extent that a negative voltage is applied to the negative
input terminal of amplifier 139, thereby setting it to a logic "1"
state. The output of amplifier 139 is applied by way of inverter
140 to AND gate 141. Also applied to AND gate 141 is the output of
amplifier 136. AND gate 141 provides a logic "1" signal on output
line 155 whenever the rotary speed is between 50 RPM and 100
RPM.
It will be noted that Zener diodes 142-148 are connected in
feedback loops from the output terminal to the negative input
terminal of each of the amplifiers 113, 114, 122, 125, 132, 136,
and 139. These Zener diodes serve the purpose of preventing the
outputs of the amplifiers from going below zero volts or above a
positive 5 volts, the outputs thereby being compatible with the
input requirements of the logic circuitry of control gate 86.
Each of these outputs from comparators 81, 83, and 85 is applied by
way of lines 150-155 to the control gate 86. It can be noted from
the previous description of comparators 81, 83, and 85 that the
logic level of the signals on lines 150-155 will be at a logic "1"
whenever the communication channels are in the conditions
represented by the legends identifying the lines 150-155 in FIG. 6.
That is, line 150, for example will be at a logic "1" level
whenever the mud flow rate is greater than 300 gallons per minute.
These six lines 150-155 which represent two conditions for each of
the three communication channels, mud flow rate, weight on bit, and
rotary speed of the drill string, are selectively combined within
the control gate 86 to provide five control signals A-E. If the mud
flow rate is less than 200 gallons per minute, line 151 is at a
logic "0" level. Line 151 is applied directly to AND gate 163 and
is applied by way of inverter 161 to the reset terminal R of
flip-flop 160. Line 150 is applied to the SET input terminal S of
the flip-flop 160. When the mud flow rate is less than 200 gallons
per minute, a logic "1" signal is applied to the reset terminal R
of flip-flop 160. This resets the Q output to a logic "0" state.
When the mud flow rate then exceeds 200 gallons per minute, a logic
"0" signal is applied to the reset terminal R, thereby removing the
reset. When the mud flow rate exceeds 300 gallons per minute, line
150 applies a logic "1" signal to the S input terminal. The Q
output terminal of flip-flop 160 is not set to a logic "1" by the
leading edge of the logic "1" input to the S terminal. This Q
output terminal of flip-flop 160 is applied to AND gate 163. When
the mud flow rate exceeds both 200 gallons per minute and 300
gallons per minute, both inputs to AND gate 163 are at a logic "1"
level and AND gate 163 provides a control signal A of a logic "1"
level. Further, control signal A remains at a logic "1" level so
long as the mud flow rate, after initially exceeding 300 gallons
per minute, remains above a 200-gallon-per-minute level. The
flip-flop 160 which was set to a logic "1" state by the mud flow
rate exceeding 300 gallons per minute is not reset to a logic "0"
state until the mud flow rate drops below 200 gallons per minute.
At this point, the signal on line 151 drops to a logic "0" state
and is applied by way of inverter 161 as a logic "1" reset signal
to the reset terminal R of flip-flop 160.
A second control signal B may be produced by combining control
signal A with the MFR signal on line 151. Control signal A is
coupled by way of line 164 and inverter 165 to one input of AND
gate 166. The MFR signal on line 151 is applied by way of line 167
to the other input of AND gate 166. The input to AND gate 166 on
line 167 is a logic "1" level whenever the MFR signal on line 151
is at a logic "1" level, indicating that the mud flow rate is
greater than 200 gallons per minute. The other input to AND gate
166 is at a logic "1" level when the control signal A is at a logic
"0" level, indicating that the mud flow rate has not exceeded 300
gallons per minute. Control signal B therefore is at a logic "1"
level whenever the mud flow rate is greater than 200 gallons per
minute and has not exceeded 300 gallons per minute since reaching
200 gallons per minute.
A third control signal C is produced by the selective combination
of control signal A, the WOB signal on line 152, and the RS signal
on line 155. Control signal C will be at a logic "1" level whenever
all three inputs to the AND gate 170 are at a logic "1" level,
thereby indicating that the mud flow rate has initially exceeded
300 gallons per minute and has not dropped below 200 gallons per
minute, that the weight on drill bit is less than 1,000 pounds, and
that the rotary speed of the drill string is greater than 50 RPM
but is less than 100 RPM.
A fourth control signal D is produced by the selective combination
of control signal A, the MFR signal on line 150, the WOB signal on
line 153, and the RS signal on line 154. The control signal D is at
a logic "1" level whenever each of the four inputs to AND gate 171
is at a logic "1" level, thereby indicating that the mud flow rate
has initially exceeded 300 gallons per minute and has then dropped
below 300 gallons per minute but still exceeds 200 gallons per
minute, that the weight on drill bit is greater than 10,000 pounds,
and that the rotary speed is less than 5 RPM.
Finally, a fifth signal E is generated by the selective combination
of the MFR signal on line 150, the WOB signal on line 153, and the
RS signal on line 154. Control signal E is therefore a logic "1"
level whenever each of the three inputs to AND gate 173 is at a
logic "1" level, indicating that the mud flow rate is greater than
200 gallons per minute, that the weight on bit is greater than
10,000 pounds, and that the rotary speed is less than 5 RPM.
The foregoing control signals A-E have been illustrated as examples
of selective combinations of those signals on lines 150-155 which
may be utilized to control downhole operations in a borehole.
In the foregoing description, surface-to-downhole communication is
initiated by changing from the surface of the earth the conditions
that exist in a plurality of communication channels and by
detecting, at the downhole location, the changes to the absolute
value of the conditions in the communication channels. In an
alternate embodiment of the present invention, any one or more of
the communication channels may have its condition time integrated
and the integral of the parameter utilized as the communication
channel. The example of turning the downhole acoustic transmitter
ON above some desired flow rate has already been discussed. Another
example which would illustrate the time integral aspect is that of
turning the acoustic transmitter ON when the mud flow rate exceeds
a certain rate and then to change the data communication format
from some initial mode to a standard transmitting mode after a
given interval of time. An example of this is the situation wherein
the initial transmitting mode is one in which sync words may come
more often than is desirable in the standard transmitting mode.
Referring now to FIG. 7 there is illustrated an integrator which
may be effectively utilized with any one of the comparators 81, 83,
or 85 of FIG. 6. For purposes of illustration, the integrator of
FIG. 7 is shown as being controlled by the output of the
weight-on-drill bit comparator 83. Specifically, the output of
amplifier 114 of the weight-on-drill-bit comparator 83 is applied
from line 153 directly to an FET switch 180. Switch 180 is utilized
to set the amplifier 181 which time integrates the reference
voltage V.sub.R when the weight on bit is greater than 10,000
pounds and which resets the amplifier 181 to zero when the weight
on bit is less than 10,000 pounds. Consequently, the amplifier 181
is zero when the signal on line 153 is logic "0" and is a smoothly
increasing function from the moment the signal on line 153 become a
logic "1". The output of amplifier 181 is negative and is fed
through a resistor 182 to the input of an amplifier 184. The
negative input terminal of amplifier 184 is held at a positive
voltage by resistor 185 until such time as the output voltage of
amplifier 181 exceeds in a negative direction the value of the
positive reference voltage V.sub.R. At such time, the input to the
amplifier 184 becomes negative and its output switches from a logic
"0" state to a logic "1" state. A Zener diode 186 is connected in a
feedback loop from the output of the amplifier 184 to its negative
input terminal. The Zener diode serves the purpose of preventing
the output of the amplifier 184 from going below zero volts or
above a positive 5 volts. The values of the resistor 187 and
capacitor 188 are selected to provide for an RC time constant of 10
seconds. When the weight on bit initially exceeds 10,000 pounds, a
logic "1" signal is applied to the input of switch 180 and the
10-second time period begins to run. At the end of the 10-second
time period, the amplifier 181 provides a negative output which
triggers the amplifier 184 to a logic "1" state. If, during this
10-second time period the weight on bit drops below 10,000 pounds,
the input to the switch 180 becomes a logic "0" signal and the
switch 180 resets the amplifier 181, thereby restarting the
10-second time period set by the RC time constant of resistor 187
and capacitor 188. Therefore, the weight-on-bit integrator of FIG.
7 is a time integrator which is at a logic "1" state only after the
weight on bit has exceeded 10,000 pounds for a continuous time
period of 10 seconds or more.
Any number of communication channels may be time integrated in
accordance with the foregoing example for the weight-on-drill-bit
communication channel. The time integrals may be utilized either
separately as control signals or in selective combinations with the
output signals representing changes, with respect to a reference
level, of the absolute value of the communication channel
conditions. The control signals so-produced may be utilized to
control a variety of downhole operations.
Control signal A has been illustrated as one example of a control
signal which may be utilized to control the operation of the
acoustic transmitter illustrated in FIGS. 2 and 3. Control signal A
may be applied as illustrated in FIG. 3 to the DC/AC inverter 53 to
enable the DC/AC inverter 53 to apply required power to the
induction motor 66 for starting the acoustic transmitter when the
mud flow rate initially exceeds 300 gallons per minute. At such
time as the mud flow rate thereafter drops below 200 gallons per
minute, the DC/AC inverter 53 is disabled by control signal A and
the induction motor 66 of the acoustic transmitter is shut
down.
Another example of the utilization of the control signals is that
of controlling, from the surface of the earth, the information
which is to be communicated upward by the acoustic transmitter. For
example, transducer 76 might provide data relating to torque,
weight on bit, temperature, resistivity, hole deviation, hole
direction, gamma ray, etc. This information is multiplexed by means
of multiplexers 77 and transmitted uphole by means of modulation of
the acoustic transmitter. It may be desirable to select only
certain of these downhole measured conditions for transmission
uphole or at what times and in what sequence such measured
conditions are transmitted uphole. The operator may wish to
telemeter only one downhole measured condition for some period of
time. In such case, the operator can, from the surface of the
earth, signal downhole by means of the available communication
channels to change the format of the multiplexers to permit
transmission of only the desired downhole measured condition. It
may, for example, be desirable to transmit this information only
when drilling operations are ceased. Therefore, a control signal
such as control signal D may be utilized wherein at least one of
the communication channel conditions required for the production of
control signal D is that the rotary speed of the drill bit string
be less than 5 RPM.
In another example, it might be advantageous to initiate
calibration of the downhole equipment from the surface of the
earth. In this manner, the operator initiates calibration by
producing, for example, the control signal C. Control signal C is
applied to the multiplexer 77 to initiate transmission of
calibration information under the condition wherein the mud flow
rate is sufficient to permit acoustic transmitter operation, the
weight on the drill bit is less than 1,000 pounds (that is,
drilling operation has effectively ceased), and the rotary speed of
the drill string is between 50 RPM and 100 RPM.
It may also be desirable to control the upward communication data
rate. This may be carried out by changing the baud setting of the
data transmission. The upward communication data rate is a function
of signal strength which reduces with depth and other factors,
thereby provision for changing the baud setting is advantageous so
that a maximum data rate consistent with signal-to-noise ratio
within the system may be maintained. An initial baud setting may be
set by utilization of control signal B, for example. In this
situation, the initial baud length is set when the mud flow rate
exceeds 200 gallons per minute but has not yet reached 300 gallons
per minute, under which circumstances the acoustic transmitter is
OFF. If at any time after the acoustic transmitter is turned ON and
it is desirable to change the initial baud setting, this may be
accomplished by setting those drilling conditions which generate
control signal E. Control signal E may be utilized, for example, to
initiate a baud change when the weight on bit is greater than
10,000 pounds, the mud flow rate is greater than 300 gallons per
minute, and the rotary speed of the drill string is less than 5
RPM. As the data communication rate is provided by the encoder 74
of the modulation unit, the initial baud setting and baud change
controls may be initiated by applying the controls B and E,
respectively, from the communication control section to the encoder
74.
Another utilization of the control signals may be that of
controlling the operation of the downhole transducers from the
surface of the earth. For example, some of these transducers may
consume excessive power from the electrical system and it may be
desirable to operate these transducers only at selective time
intervals, thereby saving electrical power. Such a control signal
may be applied to the transducers 76 to carry out this desired
control.
It is to be understood that the foregoing detailed description of
the generation of the power required to operate the acoustic
transmitter, of the transducers, and of 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 communication control system of the present
invention. This communication control system may be utilized with
various modifications to the power source, the acoustic
transmitter, the transducers, and the modulation section without
departing from the scope and spirit of the invention. Analog as
well as digital communication may be utilized. Various modulation
techniques such as, for example, amplitude modulation, frequency
shift keying, or phase shift keying may be utilized.
It is to be further understood that the circuitry illustrated in
detail in FIGS. 5, 6, and 7 is merely representative of one
embodiment of the communication control system of the present
invention. In accordance with such embodiment, the following TABLE
I sets forth specific types and values of the circuit
components.
TABLE I
Reference Designation Description Transistors 102 and 103 2N2907
(Texas Instruments) Diode D1 620 (Texas Instruments) All inverting
amplifiers MC1556G (Motorola) Flip-flop 160 SN7471 (Texas
Instruments) Switch (FET) 180 2N3993 (Motorola) All Zener diodes
1N751 (Texas Instruments) All inverters SN7400 Series (Texas
Instruments) Strain gauges 190 and 191 EA-06-250BB-500
(Micro-Measurements) Voltage V.sub.G + 15 volts DC " V.sub.H - 15
volts DC " V.sub.R + 5 volts DC
various modifications to the disclosed embodiment of the
communication control system itself, including variations in the
types and values of circuit components, 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.
* * * * *