CA1188979A - Pump noise filtering apparatus for a borehole measurement while drilling system utilizing drilling fluid pressure sensing and drilling fluid velocity sensing - Google Patents
Pump noise filtering apparatus for a borehole measurement while drilling system utilizing drilling fluid pressure sensing and drilling fluid velocity sensingInfo
- Publication number
- CA1188979A CA1188979A CA000411960A CA411960A CA1188979A CA 1188979 A CA1188979 A CA 1188979A CA 000411960 A CA000411960 A CA 000411960A CA 411960 A CA411960 A CA 411960A CA 1188979 A CA1188979 A CA 1188979A
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- drilling fluid
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- 238000005553 drilling Methods 0.000 title claims abstract description 143
- 239000012530 fluid Substances 0.000 title claims abstract description 100
- 238000005259 measurement Methods 0.000 title claims abstract description 42
- 238000001914 filtration Methods 0.000 title abstract description 13
- 230000003044 adaptive effect Effects 0.000 claims abstract description 56
- 230000015654 memory Effects 0.000 claims abstract description 26
- 230000010349 pulsation Effects 0.000 claims abstract description 23
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- 230000002596 correlated effect Effects 0.000 claims description 5
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- 230000007774 longterm Effects 0.000 claims description 3
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- 150000002500 ions Chemical class 0.000 description 3
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- 238000012545 processing Methods 0.000 description 3
- 238000009530 blood pressure measurement Methods 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 238000001228 spectrum Methods 0.000 description 2
- 230000000007 visual effect Effects 0.000 description 2
- NLZUEZXRPGMBCV-UHFFFAOYSA-N Butylhydroxytoluene Chemical compound CC1=CC(C(C)(C)C)=C(O)C(C(C)(C)C)=C1 NLZUEZXRPGMBCV-UHFFFAOYSA-N 0.000 description 1
- 230000006978 adaptation Effects 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
- E21B47/18—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
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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)
- Measuring Fluid Pressure (AREA)
- Geophysics And Detection Of Objects (AREA)
- Measurement Of The Respiration, Hearing Ability, Form, And Blood Characteristics Of Living Organisms (AREA)
- Paper (AREA)
- Investigating Or Analysing Materials By The Use Of Chemical Reactions (AREA)
- Sampling And Sample Adjustment (AREA)
Abstract
PUMP NOISE FILTERING APPARATUS FOR A
BOREHOLE MEASUREMENT WHILE DRILLING SYSTEM
UTILIZING DRILLING FLUID PRESSURE SENSING
AND DRILLING FLUID VELOCITY SENSING
Abstract of the Disclosure An apparatus for removing pulsation noise caused by a well drilling fluid circulating pump from fluid pressure pulse transmitted measurement while drilling data passing through drilling fluid in a drill string of a borehole measurement while drilling system. The noise filtering apparatus includes a drilling fluid pressure sensor, a drilling fluid velocity sensor, and an adaptive estimator that memories the pulse noise signature of a pump in synchronization with the pump's strokes. The memorized signature is removed from the signal data derived from pressure pulsations and velocity measurements in the drilling fluid in order to remove or filter the pump's noise or pressure and velocity signal disturbing influence from this data. The adaptive estimator is arranged such that it will compensate for changing operating conditions of the pump so that this pump created noise is substantially, continuously filtered from the measurement while drilling data.
BOREHOLE MEASUREMENT WHILE DRILLING SYSTEM
UTILIZING DRILLING FLUID PRESSURE SENSING
AND DRILLING FLUID VELOCITY SENSING
Abstract of the Disclosure An apparatus for removing pulsation noise caused by a well drilling fluid circulating pump from fluid pressure pulse transmitted measurement while drilling data passing through drilling fluid in a drill string of a borehole measurement while drilling system. The noise filtering apparatus includes a drilling fluid pressure sensor, a drilling fluid velocity sensor, and an adaptive estimator that memories the pulse noise signature of a pump in synchronization with the pump's strokes. The memorized signature is removed from the signal data derived from pressure pulsations and velocity measurements in the drilling fluid in order to remove or filter the pump's noise or pressure and velocity signal disturbing influence from this data. The adaptive estimator is arranged such that it will compensate for changing operating conditions of the pump so that this pump created noise is substantially, continuously filtered from the measurement while drilling data.
Description
PUMP NOISE FILTERING APPARATUS FOR A
BOREHOLE MEASUREME~T WHILE DRILLIMG SYSTEM
__ _ ,_ _ _ UTILI~I~G DRILLI~G FLUID PRESSURE SENSING
-A~D DRILLING E'LUID VELOCITY SENSI~G
Technical Field Thi8 inVentiGn iS related to da~a tran~mission systems for borehole telemetry or measurem~nt while drilling systems. More specifically the i~vention is related to a measu,rement while drilling system wherein data is transmitted from the downhole instrument through pressure pulsations of the drilling fluid within the drill string to the earth's surface. ~le invention is directed to an apparatus or il-tering data passed through pressure pulsations in the drilling Eluid rom downhole equipment to the earthls surface in order to remove the influence of data disturbing pulsations occurring because of the drillirlg Eluid circulating pump.
round o~ the Invention In the petrole~ and related borehole drilling industries there has lon~ been a need for a telemetry or measurement while drilling sy~tem to obtain real time data from the bottom of t'he borehole as i-t is being drilledO The parametric condi-tions of the en~iromnen-t in the vicini-ty of the drill bit can provide significantly valuable informa-tion to assist in the drilling of the borehole. Particularly, this information is of great assistance to make the best use of equipment and manpower needed for drilling a borehole.
There are four basic types of systems developing for the communication and to transmission of this data rom t'he bottom of the borehole to the earth's surace. These
BOREHOLE MEASUREME~T WHILE DRILLIMG SYSTEM
__ _ ,_ _ _ UTILI~I~G DRILLI~G FLUID PRESSURE SENSING
-A~D DRILLING E'LUID VELOCITY SENSI~G
Technical Field Thi8 inVentiGn iS related to da~a tran~mission systems for borehole telemetry or measurem~nt while drilling systems. More specifically the i~vention is related to a measu,rement while drilling system wherein data is transmitted from the downhole instrument through pressure pulsations of the drilling fluid within the drill string to the earth's surface. ~le invention is directed to an apparatus or il-tering data passed through pressure pulsations in the drilling Eluid rom downhole equipment to the earthls surface in order to remove the influence of data disturbing pulsations occurring because of the drillirlg Eluid circulating pump.
round o~ the Invention In the petrole~ and related borehole drilling industries there has lon~ been a need for a telemetry or measurement while drilling sy~tem to obtain real time data from the bottom of t'he borehole as i-t is being drilledO The parametric condi-tions of the en~iromnen-t in the vicini-ty of the drill bit can provide significantly valuable informa-tion to assist in the drilling of the borehole. Particularly, this information is of great assistance to make the best use of equipment and manpower needed for drilling a borehole.
There are four basic types of systems developing for the communication and to transmission of this data rom t'he bottom of the borehole to the earth's surace. These
-2-systems include transmission of the data hy electromagne-tic methods, insulated conductor or hardwire systems, acoustical methods and pressur~ pulse modulation of the drilling fluid or mud. Each of these systems has its advantages and disadvantages and the particular system with which this patent appli.cation is concerned utilizes ~he mud pressure pulse concept.
In a measurement while drilling system utilizing mud pressure pu].sation as a technique to transfer data, it is subject to interference caused by other pressure pulsations in the drilling fluid flow pathO rhe primary source of these interferring pressure pulsations is the circulating pump(s) ~or the drilling fluid or mud. This circulating pump contains a plurality of pistons, valves and other mechanical hardware that not only move the drilling fluid through the drill string but create pressure pulsations which represent noise or interference w.ith respect to the pressure pulsations produced by the transmitter of the measurement while driLling equipment.
Because the measurement while drilling system uses the drilling fluid as a pathway for transmission of data noise or pressure interference is undesirable. The noise or interference in pressure pulses p.roduced by the drilling fluid circulating pump can be of such a magnitude that it will substantially mask or obscure the data from the measurement while dr.illi.ng equipment unless .it .is properly removed by the data receiving 0quipment at the earth's surface. In study.ing this noise or interference it has been noted that the character of the interference produced by a particular drilling fluid circulating pump is not uniEorm and w.ill vary between types o~ p~nps, manufactures of purnps, and even between identical pumps at a particular drilling rig installation. Also, the characteristic pressure pwlsations for a specific pump will change in rela-tion to the operating speed of the pump. In view of -this it is observed that if a noise or interference filter iB to ~e effective in filtering or rernoving this pulse presswre interference it must be able to accor~modate the changing conditions between installations and parti~ular equipment -to be feasible for commercial operation and to be practical to accommodate changing conditions as they miyht occur on a particular drilling rig. Accordingly, it is a purpose of this invention to solve the a~ove described problem and provide a filtering s~stem to remove -this objectionable noise or interference from the drilling fluid or mud flow stream.
According to one aspect of the invention resi~es in a borehole measurement while drilling system for passing data in the form of a modula-ted data signal s-tream through drilling fluid in a drill string wherein a circui-t means is provided for substantially removing interferring pressure pulsations caused by a drilling rig's drilling fluid circulating pump from the data stream. The system includes means for generating a first signal responsive to the repetitive strokes or a drilling fluid circulating pump and means for generating a second signal responsive to fluid pressure in a drilling fluid medium that is carrying a pulsed data stream and has pressure pulses from a drillin~
fluid circulating pump. Means is provided for generating a third signal responsive to fluid velocity in the drilling fluid medium that is carrying a pulsed data stream~ and a signal combiner means is coupled to receive the secon~
signal and third signal and operably continuously subtract the third signal from the second signal thereby providing an enhanced second signal as a resultant signal. An adapti~e estimator means is adapted to receive the first signal and the second signal and retain as a stored signal a long term average representa-tion of the second signal in A sequence coordinated with the first signal and stro3ces of the pump. A subtraction means is coupled to the adaptive estimator means and the means for generating a second signal and is operable to receive the second sign~l for subtracting the stored signal from the second signal in a sequence related to the strokes of the pump such that a resultant signal is produced that is representative o~ the data signal of the borehole measurement while drilling system that was introduced into the drilling fluid.
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7~
Another aspect of the invention resides in a borehole measurement while drilling ~ystem for a drilling rig with a drill fluid circulating pump wherein a sensor is provided in a drill string adapted to sense a geophysical parameter in a borehole and produce a data signal representative of the sensed physical parameter. A
transmitter is provided for transmitting a representation of the data signal as a transmitted data signal through a drilling fluid in the drill string in a fluid pressure modulated data -transmission format. A receiver is provided at the earth's surface for receiving the transmitted d~ta signal through a pressure transducer in fluid communication with the drilling fluid in the drill string and producing an output representative of the data signal of the sensor and also representative of the sensed physical parameterO
The receiver has a filter means therein adapted to remove from the transmitted data signal the pressure pulse influence of the drilliny fluid circulating pump such that the transmitted data signal may be recovered without such inter-ference. The filter means includes a timing circuit means ~or sensing strokes of the pump and producing a timing signal representative thereo~. A signal combiner means is coupled to the pressure transducer and the velocity transducer and is operable to combine the signals fxom the transducers into an enhanced pressure data representative signal with an adaptive estimator means receiving the timing signal and the enhanced pressure data signal from -the slgnal combiner means and operable to temporarily store same data signal in correlatiorl with the timing signal and to produce an output signal in correlation with the timin~ signal that is representati~e of an extended term relation to the enhanced pressure data signal~ A subtraction means is operable to xeceive the enhanced pressure data signal and selectively remove therefrom the adaptive estimat~r output signal in correlation with the tirning signal in order to reproduce the composite data signal representative of the data signal of the sensor. The comparator means receives the - 3a -sb/Jc composite data sicJnal and has means -to compare that da-ta signal wi-th a predetermined value and determine if the composite data signal is within predetermined ~alue limits and produce therefrom an output data signal repr~sentative of the data signal of the sensor and related to the sensed geophysical parameter.
It can be seen, therefore, that the present invention provides a pump noise filtering apparatus ~or a borehole measurement while drilling system which includes an adaptive estimator having a memory that utilizes samples of pressure and velocity measurements taken from the drilling fluid flow stream in a sequence related to cyclic operation of the mud pump~ Signals relatecl to these pressure measurements are stored and then removed ~rom the continuing pressure signal measurements in a sequence correlated to the pumps cyclic operation in order to remove thîs noise or interference from the sensed data prior to passing it into a receiver, processor and display portion of the ~easurement while drilling system. The stored signal data is rereshed with each p~p cycle in order to adjust the data for changing pump noise conditions.
One object of this invention is to provide a pump naise cancelling apparatus overcoming -the aforementioned difficulty in the axt.
This invention is capable of providing a pump noise cancelling or filterin~ apparatus for a measurement while drilling system that has an adaptive estimator -that will selectively reco~nize the character and magnitude of the pressure pulse influences from a drill~g Eluid circulating pump or mud pump of a drilling r.ig and includin~
other circuitry that will selec-tively remove this influence from the pressure modulated data from the ~easurement while drilling system that is extracted ~rom the drilling fluid flow stream in the transmission of this data to the earth~s surface.
It can be further seen that this invention provides a pump noise cancelling apparatus that will adapt to chanc~ing pump noise or interference conditions in order to - 3b -sb/).~
7~
provide sub~tantially continuous reception of data that is transmitted from a downhole measurement while drilling se~sing instrument to associated receiving and processing equipment at the earth's surface.
Various other objects, advantages and features of this invention will become apparent to those akilled in the art from the following discussion, taken in conjunction with the accompanying drawings in which:
Description of the Drawings Fig. 1 is a schematic and pictorial representation of a measurement while drilling apparatus using a mud pressure modulation transmission -~echnique and installed in an earth borehole;
Fig. 2 is a schematic diagram of the receiving and noise filtering apparatus circui~ for the present invention where a single mud pump is utilized;
Fig. 3 is a more detailed schematic diagram of the noise filterillg apparatus filter circuit of this invention;
Fig. 4 is a detailed schematic of an adaptive estimator circuit that can be used in this inven-tion; and Fig. 5 is a ~chematic diagram of the noise filtering apparatus circuit for use in the present invention where a plurali-ty of mud pumps are present.
The following is a discussion and description of preferred speciEic embodiments of the pump noise iltering apparatus of this invention, ~uch being made with reeerence to the drawings, whereupon the same reference numerals are used to indicate the ~ame or similar parts and/or ~tructure. It is to be understood that ~uch discussion and description is not to unduly limit the scope oE the invention.
Detailed Description of the Preferred Embodiment This invention may be embodied in a borehole measurement while drilling system as illustrated in Fig. l. As shown the borehole measurement while drilling system is used with conventional well drilling equipment wherein a drill string lO comprised of segments of drilling pipe having a drilling bit 12 at the bottom end thereof are used to drill a borehole 14 through an earth formation 16.
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The measurement while drilling apparatus includes at least one sensor 18 in the lower portion o drill string 10 to sense a physical parameter of the geophysical borehole environment. Sensor 18 can for example be an orienta-tion device to sense the direction and inclination of the adjoining portion of the borehole, or it can be one or more other devices that are operable to measure temperature, pressure, weight applied to the bit, or a varie~y o other parameters that may be desired.
Information or data from sensor 18 is communicated to a transmitter 20 in the drill string 10. This data is then passed by transmitter 20 to the earth's surface.
Transmitter 20 in this type of measurement while drilling system is a device kno~l in the axt -to encode data from sensor 18 into pressure pulsations in the drilling Eluid or mud that is contained within drill string 10. These pressure pulsations travPl through the drilling fluid or mud upward from their point of origin at transmitter 20 to the surface equipment where the pressure pulsations are sensed by a pressure sensor 22 and the drilling fluid velocity is sensed by velocity sensor 23. Pressure sensor 22 and velocity sensor 23 are both communicably connected wi-th the interior of a conduit 24 through which the drilling fluid or mud passes. This conduit 24 is in a portion of the drilling flow loop between the drilling fluid mud pump 26 and a swivel connection 27 a-t the upper end of drill string 10.
Pressure sensor 22 and velocity sensor 23 are electrically connected with a receiver 28 that i5 used to extract the intelligence carrying data from the measurements -ta]cen ~rom the mud in drilling fluid Elow line conduit 24. The pump noise iltering or cancelling apparatus o~ this inven-tion would normally be contained within receiver 28 of this measurement while drilling system. From receiver 28 the data is transmitted to a data processor and display apparatus 30 that is operable or mathematically manipulating, further processing, and displaying the data in a desired and usable form such as a visual representa-tion, a magnetic tape or a printed document.
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Drilling fluid circulating pump 26 is the primary source of the noise or interference that is sought to be ramoved by the apparatus of this invention. For the typical oilfield operation this pump is a reciprocating piston type pump in either a duplex (two piston~ or triplex (three piston) construction. A great many of these pumps are single acting pumps however some of them may be double acting pumps. In either case they have the 1uid flow into and out o~ them controlled by check valves. The normal operation of these pumps will provide a substantially high pressure source of dri~ling fluid at a significant flow rate for the normal drilling operation as is well known in the industry. Because of the reciprocating nature of these pumps and their use of check valves, they produce pressure pulsations in the drilling fluid flow stream. The nature and characteristics of these pulsations effects both the mud's pressure and velocity and the e~tent of the effect depends upon the particular physical construction of the speciic pumpO It has been observed that these pulsations or fluctuations in the drilling fluid are cyclical in relation to the strokes of the pump and that this produces a cyclic or periodic pressure pulsation pattern in the drilling flllid as detected by pressure sensor 22 in drilling 1uid 10w line conduit 24. These pulsations also 2S effsct the drilling fluid velocity and this influence is detected by velocity sensor 23. Drilling fluicl pump 26 is itted with a pump stroke sensor to permit the monitoring of the pump's strokes at a preselected point within its pumping c~cle. This pwmp stroke sensor includes a pickup device 29 that is mechanically mounted at the pump and adapted to sense the p~lp's position at a regular occurring interval of the pump stroke cycle in order to provide data for correlating the pressure pulse cycle o~ -the drilling fluid.
The output of pump stroke sensor pickup 29 i5 connected to receiver 28.
Fig. 2 show9 a schematic representation oE the pump noise filtering or cancelling apparatus circuitry o this invention in a block diagram form. The wave forms shown at various portions of Fig. 2 indicate the shape of the various signals at the several portions of the apparatus. Pump ~6 has its pump stroke sensor connected to a timing circuit 320 The ou~put signal from the pump stroke sensor i5 a plurality of pulses spaced apart in a sequence corresponding with strokes of the pump so that timing circuit 32 can use this pump stroXe signal to generate a signal that is responsive to the repetitive stro~es of drilling fluid circulating pump 26. The output from timing circuit 32 is chosen to be a square wave as illustrated.
Pressure sensor 22 and velocity sensor 23 both provide a con~inuous sensing of the respective pressure and velocity pulsations in drilling fluid flow line conduit 24. When the measurement while drilling system is operating the output signal from pressure sensor 22 and velocity sensor 23 are i5 representative OL the combined pressure pulsat:ions of the measurement while ~rilling transmitter and the pressure pulsations emanating from drilling flui~ circulating p~p 26 because both of these are present in the drilling fluid flow line conduit 24. The wave forms of both of these signals contain some peaks that are significantly higher than others. The larger peaks are representative of positive pressure pulses from pump 26. Other peaks in this ~ave form can possibly be suspected as coming from the measurement while drilling transmitter. However specific correlation and identification of this data by only a visual examination is efective and inaccurate. The signal from pressure sensor 22 has the ~ignal rom velocity sensor 23 directed into a combiner circuit 25. Combiner circuit 25 functions to combine both o~ its input signals into a single output ~ignal. More specifically combiner circuit 25 operably subtracts the data si~nal velocity sensor 23 from the data signal of pressure sensor 23. Because the measured wave forms of these two measured parameters are similar t~e data signal resultant from the subtraction is a refin~d or ~5 improved representation of the pressure measurement data with certain velocity related disturbances or noise removed therefrom. In general this combining or subtraction process improves the signal to noise ratio vf the pressure data signal. Because the output rom combiner circuit 25 is an ~ .
enhanced or noise reduced pressure data signal it will be referred to in the following as the pressure sensor data or the pressure sensor signal. The pressure sensor data rom combiner circuit 25 is supplied to the input o an adap~ive estimator circuit 34 and also into a subtraction c,ircuit 36. The output from adaptive estimator circuit 34 is also directed into subtract,ion circuit 36.
Adaptive estimator circuit .i5 connected to receive -the output from timing circuit 32, to receive the enchanced pressure sensor signal from combiner circuit 25, and provide an output that is fed in~o subtraction circuit 36. Adaptive e~timator circuit 34 is provided with circuitry to memorize or store data that is representative of specific portions of the pressure sensor output signal from combiner circuit 25 in correspondence with strokes of the pump and in correlation with the output signal from timing circuit 32, The input to adaptive estimator 34 is divided into a plurality pressure data sample segmen-ts between like portions of each pump stroke interval. During each pressure data sample segment the enhanced pressure sensor data is sampled by and stored in adaptive estimator circuit 34.
Thus for each stroke of the pump (one pump stroke interval) a plurality of samples of -the enhanced pressure sensor data are taken (one in each pressure sample segment). As these samples of the pressure data are accumulated the stored or representative value in adaptive estimator circui-t can be changed with each repetitive stroke oE the pump. r~is is done in order to permit the data stored in the adaptive estimator circuit to closely follow the pumps operation and t~us accommodate changing operatin~ conditions. This adaptive estimator circuit 34 performs the function of a tracking commutative ~ilter which is to estimate the approximate value of the following data sample in each pressure sample segment by retaining the sum of previous such weighted values and modifying or adjusting that ~alue to correspond with a new data sample during that particular pressure sample segment o~ each pump stroke interval.
This adaptive estimator circuit 34 includes a memory that functions to retain a representative of the data from the pressure sensor. This memory must be capable of adapting or varying its retained data to accommodate changing data that is resultant ~rom the operating conditions at a well. In general the adaptive estimator circuit 34 functions as a specific adaptation of a filter generally Xnown as a tracking commutative filter. An example of such a changing condi~ion is a simple change in the pump's opera~ing speed that would affect -the pulse rate from the pump stroke sensorO An additional change that might influence the pump's pressure pulse characteristics would be raising the drill string from the drilling position so that drill bit 12 instead of being a-t the bottom o the borehole is in an elevated position a short distance above the borehole bottom. This is a condition that might be used or temporary circulation of the drilling fluid.
The memory of adaptive estimator circui-t 34 can be an analog type memory circuit or it can be a digital type memory circuit depending upon the desire of the designer.
Regardless of which type of memory circuit is used the operable parameters are the same because of the needed function this portion oE the apparatus. For illustra-tion of a specific memory configuration Figs. 3 and 5 depict an analog memory circuit that can be used with -the apparatus and method of this invention. The circui~ of Fig. 5 will be described in greater detail following -the description of Figs. 1-3.
Returning to the description of Figs. 1 and 2 subtraction circuit 36 is provided with an input Erom combiner circuit 25 and an input from adaptive estimator circuit 34. Subtraction circuit 36 functions to remove from the pressure sensor signal those por-tions which are indicative Oe the pressure pulsations -that are sequenced with and related to drilling fluid circulating pump 26.
This removal of the selec~ed portions of ~he data signal from the pressure sensor data is done in correlation with the pump strokes as by -timing circuit 32. Removal of these portions of the pressure sensor signal is done by subtracting from the pressure sensor data a valu2 representa-tive of those portions of the pressure sensor ~10--data which occur in a repetitive, correlatable sequence with the pump's strokes~ m e resultan-t signal from this subtraction or removal process carries the intelligence data from the transmit-ter of the measurement while drilling apparatus with the dlstorting influence of drilling fluid circulating pump 26 having been substantially removedO A
wave form generally representative of this sign~l is shown in Fig. 2 between subtraction circuit 36 and 38.
Comparator 38 performs a function of comparing the output signal ~rom subtraction circuit 36 wi-th a predetermined signal value in order to eliminate spurious or extraneous portions of the data signal prior to passing the signal to the receiver, processor and display in order to reduce the possibility of erroneous data. Comparator 38 includes a circuit that compares the value of the data signal with a predetermined value or range of values ~at the desire of the user) and from this signal the comparator provides an output signal indicative of and timewise correlatable with the data siynal that is representative oE
those portions of the data signal that meet the criteria oE
being greater than or being wi-thin a predetermined range of values. A wave form representative of the output of comparator 38 is illustrated in Fig. 2. From comparator 38 the data signal shown i5 in a form that can be utilized by appropriate digital, encoding equipment and circuitry to remove and decode the intelligence data from the signal.
~epending upon the apparatus used the output from comparator 38 can pass into a decodiny portion of the receiver or processor Eor further data manipulation, handling, etc.
Fig. 3 shows in block diagram schematic form an embodiment of the adaptive estimator circuit and the subtraction circuit portions of this inven-tion. Pump stroke sensor 40 associated with drilling fluid circulating pump 26 provides a pulsed output signal as shown. This output signal is fed into a flip flop circuit 42 -that shapes the signal in-to a rectangular wave form as illustrated. Phase lock loop circuit 44 receives the output from flip flop circuit 42 and functions to synchronize its outpu-t timing pulses with the timing pulse signal from pump stroke sensor 7~
40 so -that each timing pulse from flip flop circuit 42 occupies a fixed and constant time in-~erval with respect to the pump stroke cycle. The output from phase lock loop circuit 44 is ~onnected -to an input of adap~ive estimator circuit 34.
Combiner circuit 25 has its output signal connscted to the input of a buffer amplifier 46 that functions to condition the magnitude of the pressure signal data for use by the adaptive estimator circuit and in other portions of the circui-t. A generally representative wave form of this data signal is illustrated in Fig. 3 between combiner circuit 25 and bufEer 46~
It is to be noted that this wave form is only generally representative of the wave form that can occur at this location. The specific shape of the t~pical or representative wave form will vary depending upon the speed of operation of the drilling fluid circulating pump and also upon the static pressure and the velocity of fluid in the drilling fluid conduit 24. Because this wave form i5 subject to some changes in shape it will influence the wave form output from adder circuit 50. q~he illustrated wave -forms shown in Figs. 2 and 3 are to be considered as approximate or representative or illustrative of the actual wave forms that may be present in actual practice o:~ this invention.
Adaptive estimator 34 is described above and funct.~ons -to prewhiten or process before manipulation the data signal received from buffer 46 duri.ng the pressure sample time segments designated by the timing c:ircuit. It receives 6ignals :Erom phase lock loop 44 and from buf:Eer 46 and provides a data signal to the input of an inverter 48.
The subtraction portion of this circuit is accomplished in this embodiment by an inverting amplifier 48 coupled with an adding amplifier circuit or adder 50.
Inverting amplifier 48 inverts or changes the sign of the data signal from adaptive memory 34 so -that when it is added to -the data signal from buffer 46 the result will be an additive removal or subtraction of the representations of -the selec~ed pressure pulse characteri6tics stored in the 37~
memory of adaptive estimator 34 from the pressure signal data signal output of buffer 46~ rrhe resultant data signal output from adder 50 can be in a wave form that has a plurality of well defined peaks as illustrated in Fig. 3.
This resultant data signal is then supplied to comparator 38 for selection of the output data siynal by comparing the received data signal with predetermined reference values as described previously.
An example of an analog typ~ of adaptive es-timator is shown in Fig. 4. The circuit sho~m in Fig. 4 includes an analog type of memory and other analog devices to interface with other connecting portions of the circuitry in this apparatus. Similar elements in Fi~s. 3 and 4 have the same numerals. The pressure pulse related data signal from combiner circuit 25 is supplied to the input of buffer 46.
The output of bufer 46 is divided with one portion going to the input of inverter 48 and the other portion going to the input of the adaptive memory or tracking commutative filter, The adaptive memory or tracking commutative filter has a plurality of capacitors 52 connected in parallel between a buss line 55 carrying the output from buffer 46 and a multiplexing circuit 54. Multiplexing circui-~ 54 basically functions as a plurality of switches that function to connect the plurality of capacitors 52 one at a time between ground and buss line 55 in sequence with timing signals rom phase lock loop circuit 44. Multiplexirly circuit 54 can be a convent:ional integrated circui-t having a plurality of multiplexing parts corresponding with the num~er of pressure sample segments that are selected for divisiorls of t.he pump stroke interval. The clock or timing sequence input to multip:Lexer 54 is through a plurality o~
connections rom phase lock loop ciruit 44, For each purnp stroke interval the plurality of capacitors are each sequentially connected during their associated portion of the pump stroke interval or during their designated pressure sample segment of that interval. The capacitors are each charged to a value approximating the value of the data signal during the interval in which they are individually connected. Charging the capacitors in this manner provides a long term average of the data signal value during the pressure sample segment time interval as is well known in commutative filters.
The output from this adaptive memory ls via the buss line 55 to a gain amplifier 56. The OUtpllt of gain amplifier 56 and the output of inverter 48 are combined at adder 50 (enclosed in dashed lines) with the composi-te resulting signal being additionally increased by another gain amplifier 58. The output of amplifier 58 is connected to the input of comparator 38 or comparison of the processed data signal with a predetermined value or range of values as described in the preceding.
In the situations where a plurality of drilling 1uid circulating pumps are used in a drilling rig ~aving a measurement while drilling apparatus it is necessary to provide a plurality of cascaded pump noise filtering devices in order to selectively remove the noise or pressure and velocity pulsa-tion influence of these specific pumps.
Fig~ 5 illustrates in schematic block diagram form such a pump noise filtering apparatus which is representative of that which could be utilized to filter the pump noise or interference in the pressure pulse data for a drilling rig having two or more drilling fluid circulating pumps. The circuit shown in Fig. 5 includes a pressure sensor 60 a velocity sensor 61a and an associatecl combiner circuit 63 adapted to sense the pressure signaL
data on a drilling rig in khe drilling fluid flow conduit at a point betwe~n the location where fluid Elow Erom the plurality of mud p~p flow conduits merga and the location w~ere this combined flow passes into the drill string. This circuit is sllown with a pair of drilling fluid circulating pumps identified as a first pump 62 and a second pump 64.
In this circuit the effect of the first pump 62 is first removed from the data signal then the effect of the second pump 64 is removed from -the data signal. The first pump 62 is provided with a pump stroke counter circuit that provides pump stroke timing signals to first timing circuit 66. Data from firs-t timing circuit 66 and the drilling fluid pressure signal data from combiner circuit 63 are supplied to a first adaptive memory 68. ~his fluid pressure data signal is supplied as an input to first adaptive es-timator circuit 68. The output from first adaptive estimator 68 is supplied to a first subtraction circuit 70 along wi-th the pressure sensor signal from combiner circuit 63. The output from first subtraction circuit 70 is essentially th~ pressure signal data of the pressure and velocity com~inr circuit 63 with the effect of the first pump 62 removed therefrom.
This data provides the input to the following portion of the circuit that eliminates or filters the effect of the second pump 64.
Second pump 64 is provided with a pump stroke counter circuit the output of which provides sequential pump stroke data to the input of second timing circuit 72. The output from second t~ming circui-t 72 is to one input of second adaptive estimator 74 along with an input from first subtraction circuit 70. ~he output of second adaptive estimator 74 is coupled to one input of second subtraction circuit 76. An output from first subtraction circuit 70 is provided to second subtraction circuit 76. The ou~put from second subtraction circuit 76 has the effect of pressure and velocity pulse interEerence from both pumps 62 and 64 removed or ~iltered from the data and this data is supplied to comparator 78 for comparison with a preselected range of values as described above. The output from comparator 78 is to a data receiver, processor and display essen-tiaLly as described in the preceding embodiment.
In the use and operation of the pump noise flltering apparatus of this invention, i-t is seen -that the same provides a combination of apparatus and circuitry for substantially removing the noise or interference caused by a drilling rig's well drilling fluid circulating pump into the data communication medium for a pressure pulse modulated type syst~m of communication in a measurement while drilling system. This invention is operable with mud pressure modulated communication systems utilizing positive or negative signal pressures and continuous wave or pulse modulation. Although this invention is described wi~ a pressure pulse modulat~d data transmission system it ;s to be understood that it is equally operable with other modulation systems. ~ecause of the adaptive estimator this apparatus will adapt itself to the particular pump and pump noise environment of a particular drilling rig. Also since t,he form of memory used in the adaptive estima-tor can be either an analog form or a digital form depending upon the equipment choice of the user. Thig apparatus can be used with installations having a single pump or installations having multiple pump5. Because the adaptive estimator is sequenced with the strokes of the associated pump it is in effect tuned to memorize representations of the data signal spectrum in which the pressure data signal i5 contained.
Thus, when the memorized signal is removed from the entire spectrum in a selective manner coordinated with the pump strokes it is adapted to remove a representation of the noise due to the pump. Because this particular noise is the major contributor to noise or interference in this pressure medium it removes the undesirable portions of the pressure pulse data signal -thereby in effect filtering the da-ta signal so tha-t it can be easily and accurately converted to a usable digital or analog form compatible with the measurement while drilling systems processing and recording equipment.
~lthough specific preferred embodiments oE this invention have been described in detail in the preceding description. rrhis description is not intended -to limit the invention to the particular form or embodiments disclosed h~rein since they are to be recognized as illustrative rather than restrictive and it would be obvious to -those skilled in the art that the invention is not so limited.
For example, the described analog memory could be a digital memory provided with appropriate analog to di~ital conversion circuitry. ALso provided that a digital memory is used the conversion from an analog signal to a digital signal could be made at the pressure and veloci-ty sensors and at the pump sensor if desired.
Thus the invention is declared to cover all changes and modifications of the specific example of the invention herein disclosed for purposes of illustration 7~3 which does not constitute departures ~rom the spirit and scope of the invention.
In a measurement while drilling system utilizing mud pressure pu].sation as a technique to transfer data, it is subject to interference caused by other pressure pulsations in the drilling fluid flow pathO rhe primary source of these interferring pressure pulsations is the circulating pump(s) ~or the drilling fluid or mud. This circulating pump contains a plurality of pistons, valves and other mechanical hardware that not only move the drilling fluid through the drill string but create pressure pulsations which represent noise or interference w.ith respect to the pressure pulsations produced by the transmitter of the measurement while driLling equipment.
Because the measurement while drilling system uses the drilling fluid as a pathway for transmission of data noise or pressure interference is undesirable. The noise or interference in pressure pulses p.roduced by the drilling fluid circulating pump can be of such a magnitude that it will substantially mask or obscure the data from the measurement while dr.illi.ng equipment unless .it .is properly removed by the data receiving 0quipment at the earth's surface. In study.ing this noise or interference it has been noted that the character of the interference produced by a particular drilling fluid circulating pump is not uniEorm and w.ill vary between types o~ p~nps, manufactures of purnps, and even between identical pumps at a particular drilling rig installation. Also, the characteristic pressure pwlsations for a specific pump will change in rela-tion to the operating speed of the pump. In view of -this it is observed that if a noise or interference filter iB to ~e effective in filtering or rernoving this pulse presswre interference it must be able to accor~modate the changing conditions between installations and parti~ular equipment -to be feasible for commercial operation and to be practical to accommodate changing conditions as they miyht occur on a particular drilling rig. Accordingly, it is a purpose of this invention to solve the a~ove described problem and provide a filtering s~stem to remove -this objectionable noise or interference from the drilling fluid or mud flow stream.
According to one aspect of the invention resi~es in a borehole measurement while drilling system for passing data in the form of a modula-ted data signal s-tream through drilling fluid in a drill string wherein a circui-t means is provided for substantially removing interferring pressure pulsations caused by a drilling rig's drilling fluid circulating pump from the data stream. The system includes means for generating a first signal responsive to the repetitive strokes or a drilling fluid circulating pump and means for generating a second signal responsive to fluid pressure in a drilling fluid medium that is carrying a pulsed data stream and has pressure pulses from a drillin~
fluid circulating pump. Means is provided for generating a third signal responsive to fluid velocity in the drilling fluid medium that is carrying a pulsed data stream~ and a signal combiner means is coupled to receive the secon~
signal and third signal and operably continuously subtract the third signal from the second signal thereby providing an enhanced second signal as a resultant signal. An adapti~e estimator means is adapted to receive the first signal and the second signal and retain as a stored signal a long term average representa-tion of the second signal in A sequence coordinated with the first signal and stro3ces of the pump. A subtraction means is coupled to the adaptive estimator means and the means for generating a second signal and is operable to receive the second sign~l for subtracting the stored signal from the second signal in a sequence related to the strokes of the pump such that a resultant signal is produced that is representative o~ the data signal of the borehole measurement while drilling system that was introduced into the drilling fluid.
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Another aspect of the invention resides in a borehole measurement while drilling ~ystem for a drilling rig with a drill fluid circulating pump wherein a sensor is provided in a drill string adapted to sense a geophysical parameter in a borehole and produce a data signal representative of the sensed physical parameter. A
transmitter is provided for transmitting a representation of the data signal as a transmitted data signal through a drilling fluid in the drill string in a fluid pressure modulated data -transmission format. A receiver is provided at the earth's surface for receiving the transmitted d~ta signal through a pressure transducer in fluid communication with the drilling fluid in the drill string and producing an output representative of the data signal of the sensor and also representative of the sensed physical parameterO
The receiver has a filter means therein adapted to remove from the transmitted data signal the pressure pulse influence of the drilliny fluid circulating pump such that the transmitted data signal may be recovered without such inter-ference. The filter means includes a timing circuit means ~or sensing strokes of the pump and producing a timing signal representative thereo~. A signal combiner means is coupled to the pressure transducer and the velocity transducer and is operable to combine the signals fxom the transducers into an enhanced pressure data representative signal with an adaptive estimator means receiving the timing signal and the enhanced pressure data signal from -the slgnal combiner means and operable to temporarily store same data signal in correlatiorl with the timing signal and to produce an output signal in correlation with the timin~ signal that is representati~e of an extended term relation to the enhanced pressure data signal~ A subtraction means is operable to xeceive the enhanced pressure data signal and selectively remove therefrom the adaptive estimat~r output signal in correlation with the tirning signal in order to reproduce the composite data signal representative of the data signal of the sensor. The comparator means receives the - 3a -sb/Jc composite data sicJnal and has means -to compare that da-ta signal wi-th a predetermined value and determine if the composite data signal is within predetermined ~alue limits and produce therefrom an output data signal repr~sentative of the data signal of the sensor and related to the sensed geophysical parameter.
It can be seen, therefore, that the present invention provides a pump noise filtering apparatus ~or a borehole measurement while drilling system which includes an adaptive estimator having a memory that utilizes samples of pressure and velocity measurements taken from the drilling fluid flow stream in a sequence related to cyclic operation of the mud pump~ Signals relatecl to these pressure measurements are stored and then removed ~rom the continuing pressure signal measurements in a sequence correlated to the pumps cyclic operation in order to remove thîs noise or interference from the sensed data prior to passing it into a receiver, processor and display portion of the ~easurement while drilling system. The stored signal data is rereshed with each p~p cycle in order to adjust the data for changing pump noise conditions.
One object of this invention is to provide a pump naise cancelling apparatus overcoming -the aforementioned difficulty in the axt.
This invention is capable of providing a pump noise cancelling or filterin~ apparatus for a measurement while drilling system that has an adaptive estimator -that will selectively reco~nize the character and magnitude of the pressure pulse influences from a drill~g Eluid circulating pump or mud pump of a drilling r.ig and includin~
other circuitry that will selec-tively remove this influence from the pressure modulated data from the ~easurement while drilling system that is extracted ~rom the drilling fluid flow stream in the transmission of this data to the earth~s surface.
It can be further seen that this invention provides a pump noise cancelling apparatus that will adapt to chanc~ing pump noise or interference conditions in order to - 3b -sb/).~
7~
provide sub~tantially continuous reception of data that is transmitted from a downhole measurement while drilling se~sing instrument to associated receiving and processing equipment at the earth's surface.
Various other objects, advantages and features of this invention will become apparent to those akilled in the art from the following discussion, taken in conjunction with the accompanying drawings in which:
Description of the Drawings Fig. 1 is a schematic and pictorial representation of a measurement while drilling apparatus using a mud pressure modulation transmission -~echnique and installed in an earth borehole;
Fig. 2 is a schematic diagram of the receiving and noise filtering apparatus circui~ for the present invention where a single mud pump is utilized;
Fig. 3 is a more detailed schematic diagram of the noise filterillg apparatus filter circuit of this invention;
Fig. 4 is a detailed schematic of an adaptive estimator circuit that can be used in this inven-tion; and Fig. 5 is a ~chematic diagram of the noise filtering apparatus circuit for use in the present invention where a plurali-ty of mud pumps are present.
The following is a discussion and description of preferred speciEic embodiments of the pump noise iltering apparatus of this invention, ~uch being made with reeerence to the drawings, whereupon the same reference numerals are used to indicate the ~ame or similar parts and/or ~tructure. It is to be understood that ~uch discussion and description is not to unduly limit the scope oE the invention.
Detailed Description of the Preferred Embodiment This invention may be embodied in a borehole measurement while drilling system as illustrated in Fig. l. As shown the borehole measurement while drilling system is used with conventional well drilling equipment wherein a drill string lO comprised of segments of drilling pipe having a drilling bit 12 at the bottom end thereof are used to drill a borehole 14 through an earth formation 16.
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The measurement while drilling apparatus includes at least one sensor 18 in the lower portion o drill string 10 to sense a physical parameter of the geophysical borehole environment. Sensor 18 can for example be an orienta-tion device to sense the direction and inclination of the adjoining portion of the borehole, or it can be one or more other devices that are operable to measure temperature, pressure, weight applied to the bit, or a varie~y o other parameters that may be desired.
Information or data from sensor 18 is communicated to a transmitter 20 in the drill string 10. This data is then passed by transmitter 20 to the earth's surface.
Transmitter 20 in this type of measurement while drilling system is a device kno~l in the axt -to encode data from sensor 18 into pressure pulsations in the drilling Eluid or mud that is contained within drill string 10. These pressure pulsations travPl through the drilling fluid or mud upward from their point of origin at transmitter 20 to the surface equipment where the pressure pulsations are sensed by a pressure sensor 22 and the drilling fluid velocity is sensed by velocity sensor 23. Pressure sensor 22 and velocity sensor 23 are both communicably connected wi-th the interior of a conduit 24 through which the drilling fluid or mud passes. This conduit 24 is in a portion of the drilling flow loop between the drilling fluid mud pump 26 and a swivel connection 27 a-t the upper end of drill string 10.
Pressure sensor 22 and velocity sensor 23 are electrically connected with a receiver 28 that i5 used to extract the intelligence carrying data from the measurements -ta]cen ~rom the mud in drilling fluid Elow line conduit 24. The pump noise iltering or cancelling apparatus o~ this inven-tion would normally be contained within receiver 28 of this measurement while drilling system. From receiver 28 the data is transmitted to a data processor and display apparatus 30 that is operable or mathematically manipulating, further processing, and displaying the data in a desired and usable form such as a visual representa-tion, a magnetic tape or a printed document.
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Drilling fluid circulating pump 26 is the primary source of the noise or interference that is sought to be ramoved by the apparatus of this invention. For the typical oilfield operation this pump is a reciprocating piston type pump in either a duplex (two piston~ or triplex (three piston) construction. A great many of these pumps are single acting pumps however some of them may be double acting pumps. In either case they have the 1uid flow into and out o~ them controlled by check valves. The normal operation of these pumps will provide a substantially high pressure source of dri~ling fluid at a significant flow rate for the normal drilling operation as is well known in the industry. Because of the reciprocating nature of these pumps and their use of check valves, they produce pressure pulsations in the drilling fluid flow stream. The nature and characteristics of these pulsations effects both the mud's pressure and velocity and the e~tent of the effect depends upon the particular physical construction of the speciic pumpO It has been observed that these pulsations or fluctuations in the drilling fluid are cyclical in relation to the strokes of the pump and that this produces a cyclic or periodic pressure pulsation pattern in the drilling flllid as detected by pressure sensor 22 in drilling 1uid 10w line conduit 24. These pulsations also 2S effsct the drilling fluid velocity and this influence is detected by velocity sensor 23. Drilling fluicl pump 26 is itted with a pump stroke sensor to permit the monitoring of the pump's strokes at a preselected point within its pumping c~cle. This pwmp stroke sensor includes a pickup device 29 that is mechanically mounted at the pump and adapted to sense the p~lp's position at a regular occurring interval of the pump stroke cycle in order to provide data for correlating the pressure pulse cycle o~ -the drilling fluid.
The output of pump stroke sensor pickup 29 i5 connected to receiver 28.
Fig. 2 show9 a schematic representation oE the pump noise filtering or cancelling apparatus circuitry o this invention in a block diagram form. The wave forms shown at various portions of Fig. 2 indicate the shape of the various signals at the several portions of the apparatus. Pump ~6 has its pump stroke sensor connected to a timing circuit 320 The ou~put signal from the pump stroke sensor i5 a plurality of pulses spaced apart in a sequence corresponding with strokes of the pump so that timing circuit 32 can use this pump stroXe signal to generate a signal that is responsive to the repetitive stro~es of drilling fluid circulating pump 26. The output from timing circuit 32 is chosen to be a square wave as illustrated.
Pressure sensor 22 and velocity sensor 23 both provide a con~inuous sensing of the respective pressure and velocity pulsations in drilling fluid flow line conduit 24. When the measurement while drilling system is operating the output signal from pressure sensor 22 and velocity sensor 23 are i5 representative OL the combined pressure pulsat:ions of the measurement while ~rilling transmitter and the pressure pulsations emanating from drilling flui~ circulating p~p 26 because both of these are present in the drilling fluid flow line conduit 24. The wave forms of both of these signals contain some peaks that are significantly higher than others. The larger peaks are representative of positive pressure pulses from pump 26. Other peaks in this ~ave form can possibly be suspected as coming from the measurement while drilling transmitter. However specific correlation and identification of this data by only a visual examination is efective and inaccurate. The signal from pressure sensor 22 has the ~ignal rom velocity sensor 23 directed into a combiner circuit 25. Combiner circuit 25 functions to combine both o~ its input signals into a single output ~ignal. More specifically combiner circuit 25 operably subtracts the data si~nal velocity sensor 23 from the data signal of pressure sensor 23. Because the measured wave forms of these two measured parameters are similar t~e data signal resultant from the subtraction is a refin~d or ~5 improved representation of the pressure measurement data with certain velocity related disturbances or noise removed therefrom. In general this combining or subtraction process improves the signal to noise ratio vf the pressure data signal. Because the output rom combiner circuit 25 is an ~ .
enhanced or noise reduced pressure data signal it will be referred to in the following as the pressure sensor data or the pressure sensor signal. The pressure sensor data rom combiner circuit 25 is supplied to the input o an adap~ive estimator circuit 34 and also into a subtraction c,ircuit 36. The output from adaptive estimator circuit 34 is also directed into subtract,ion circuit 36.
Adaptive estimator circuit .i5 connected to receive -the output from timing circuit 32, to receive the enchanced pressure sensor signal from combiner circuit 25, and provide an output that is fed in~o subtraction circuit 36. Adaptive e~timator circuit 34 is provided with circuitry to memorize or store data that is representative of specific portions of the pressure sensor output signal from combiner circuit 25 in correspondence with strokes of the pump and in correlation with the output signal from timing circuit 32, The input to adaptive estimator 34 is divided into a plurality pressure data sample segmen-ts between like portions of each pump stroke interval. During each pressure data sample segment the enhanced pressure sensor data is sampled by and stored in adaptive estimator circuit 34.
Thus for each stroke of the pump (one pump stroke interval) a plurality of samples of -the enhanced pressure sensor data are taken (one in each pressure sample segment). As these samples of the pressure data are accumulated the stored or representative value in adaptive estimator circui-t can be changed with each repetitive stroke oE the pump. r~is is done in order to permit the data stored in the adaptive estimator circuit to closely follow the pumps operation and t~us accommodate changing operatin~ conditions. This adaptive estimator circuit 34 performs the function of a tracking commutative ~ilter which is to estimate the approximate value of the following data sample in each pressure sample segment by retaining the sum of previous such weighted values and modifying or adjusting that ~alue to correspond with a new data sample during that particular pressure sample segment o~ each pump stroke interval.
This adaptive estimator circuit 34 includes a memory that functions to retain a representative of the data from the pressure sensor. This memory must be capable of adapting or varying its retained data to accommodate changing data that is resultant ~rom the operating conditions at a well. In general the adaptive estimator circuit 34 functions as a specific adaptation of a filter generally Xnown as a tracking commutative filter. An example of such a changing condi~ion is a simple change in the pump's opera~ing speed that would affect -the pulse rate from the pump stroke sensorO An additional change that might influence the pump's pressure pulse characteristics would be raising the drill string from the drilling position so that drill bit 12 instead of being a-t the bottom o the borehole is in an elevated position a short distance above the borehole bottom. This is a condition that might be used or temporary circulation of the drilling fluid.
The memory of adaptive estimator circui-t 34 can be an analog type memory circuit or it can be a digital type memory circuit depending upon the desire of the designer.
Regardless of which type of memory circuit is used the operable parameters are the same because of the needed function this portion oE the apparatus. For illustra-tion of a specific memory configuration Figs. 3 and 5 depict an analog memory circuit that can be used with -the apparatus and method of this invention. The circui~ of Fig. 5 will be described in greater detail following -the description of Figs. 1-3.
Returning to the description of Figs. 1 and 2 subtraction circuit 36 is provided with an input Erom combiner circuit 25 and an input from adaptive estimator circuit 34. Subtraction circuit 36 functions to remove from the pressure sensor signal those por-tions which are indicative Oe the pressure pulsations -that are sequenced with and related to drilling fluid circulating pump 26.
This removal of the selec~ed portions of ~he data signal from the pressure sensor data is done in correlation with the pump strokes as by -timing circuit 32. Removal of these portions of the pressure sensor signal is done by subtracting from the pressure sensor data a valu2 representa-tive of those portions of the pressure sensor ~10--data which occur in a repetitive, correlatable sequence with the pump's strokes~ m e resultan-t signal from this subtraction or removal process carries the intelligence data from the transmit-ter of the measurement while drilling apparatus with the dlstorting influence of drilling fluid circulating pump 26 having been substantially removedO A
wave form generally representative of this sign~l is shown in Fig. 2 between subtraction circuit 36 and 38.
Comparator 38 performs a function of comparing the output signal ~rom subtraction circuit 36 wi-th a predetermined signal value in order to eliminate spurious or extraneous portions of the data signal prior to passing the signal to the receiver, processor and display in order to reduce the possibility of erroneous data. Comparator 38 includes a circuit that compares the value of the data signal with a predetermined value or range of values ~at the desire of the user) and from this signal the comparator provides an output signal indicative of and timewise correlatable with the data siynal that is representative oE
those portions of the data signal that meet the criteria oE
being greater than or being wi-thin a predetermined range of values. A wave form representative of the output of comparator 38 is illustrated in Fig. 2. From comparator 38 the data signal shown i5 in a form that can be utilized by appropriate digital, encoding equipment and circuitry to remove and decode the intelligence data from the signal.
~epending upon the apparatus used the output from comparator 38 can pass into a decodiny portion of the receiver or processor Eor further data manipulation, handling, etc.
Fig. 3 shows in block diagram schematic form an embodiment of the adaptive estimator circuit and the subtraction circuit portions of this inven-tion. Pump stroke sensor 40 associated with drilling fluid circulating pump 26 provides a pulsed output signal as shown. This output signal is fed into a flip flop circuit 42 -that shapes the signal in-to a rectangular wave form as illustrated. Phase lock loop circuit 44 receives the output from flip flop circuit 42 and functions to synchronize its outpu-t timing pulses with the timing pulse signal from pump stroke sensor 7~
40 so -that each timing pulse from flip flop circuit 42 occupies a fixed and constant time in-~erval with respect to the pump stroke cycle. The output from phase lock loop circuit 44 is ~onnected -to an input of adap~ive estimator circuit 34.
Combiner circuit 25 has its output signal connscted to the input of a buffer amplifier 46 that functions to condition the magnitude of the pressure signal data for use by the adaptive estimator circuit and in other portions of the circui-t. A generally representative wave form of this data signal is illustrated in Fig. 3 between combiner circuit 25 and bufEer 46~
It is to be noted that this wave form is only generally representative of the wave form that can occur at this location. The specific shape of the t~pical or representative wave form will vary depending upon the speed of operation of the drilling fluid circulating pump and also upon the static pressure and the velocity of fluid in the drilling fluid conduit 24. Because this wave form i5 subject to some changes in shape it will influence the wave form output from adder circuit 50. q~he illustrated wave -forms shown in Figs. 2 and 3 are to be considered as approximate or representative or illustrative of the actual wave forms that may be present in actual practice o:~ this invention.
Adaptive estimator 34 is described above and funct.~ons -to prewhiten or process before manipulation the data signal received from buffer 46 duri.ng the pressure sample time segments designated by the timing c:ircuit. It receives 6ignals :Erom phase lock loop 44 and from buf:Eer 46 and provides a data signal to the input of an inverter 48.
The subtraction portion of this circuit is accomplished in this embodiment by an inverting amplifier 48 coupled with an adding amplifier circuit or adder 50.
Inverting amplifier 48 inverts or changes the sign of the data signal from adaptive memory 34 so -that when it is added to -the data signal from buffer 46 the result will be an additive removal or subtraction of the representations of -the selec~ed pressure pulse characteri6tics stored in the 37~
memory of adaptive estimator 34 from the pressure signal data signal output of buffer 46~ rrhe resultant data signal output from adder 50 can be in a wave form that has a plurality of well defined peaks as illustrated in Fig. 3.
This resultant data signal is then supplied to comparator 38 for selection of the output data siynal by comparing the received data signal with predetermined reference values as described previously.
An example of an analog typ~ of adaptive es-timator is shown in Fig. 4. The circuit sho~m in Fig. 4 includes an analog type of memory and other analog devices to interface with other connecting portions of the circuitry in this apparatus. Similar elements in Fi~s. 3 and 4 have the same numerals. The pressure pulse related data signal from combiner circuit 25 is supplied to the input of buffer 46.
The output of bufer 46 is divided with one portion going to the input of inverter 48 and the other portion going to the input of the adaptive memory or tracking commutative filter, The adaptive memory or tracking commutative filter has a plurality of capacitors 52 connected in parallel between a buss line 55 carrying the output from buffer 46 and a multiplexing circuit 54. Multiplexing circui-~ 54 basically functions as a plurality of switches that function to connect the plurality of capacitors 52 one at a time between ground and buss line 55 in sequence with timing signals rom phase lock loop circuit 44. Multiplexirly circuit 54 can be a convent:ional integrated circui-t having a plurality of multiplexing parts corresponding with the num~er of pressure sample segments that are selected for divisiorls of t.he pump stroke interval. The clock or timing sequence input to multip:Lexer 54 is through a plurality o~
connections rom phase lock loop ciruit 44, For each purnp stroke interval the plurality of capacitors are each sequentially connected during their associated portion of the pump stroke interval or during their designated pressure sample segment of that interval. The capacitors are each charged to a value approximating the value of the data signal during the interval in which they are individually connected. Charging the capacitors in this manner provides a long term average of the data signal value during the pressure sample segment time interval as is well known in commutative filters.
The output from this adaptive memory ls via the buss line 55 to a gain amplifier 56. The OUtpllt of gain amplifier 56 and the output of inverter 48 are combined at adder 50 (enclosed in dashed lines) with the composi-te resulting signal being additionally increased by another gain amplifier 58. The output of amplifier 58 is connected to the input of comparator 38 or comparison of the processed data signal with a predetermined value or range of values as described in the preceding.
In the situations where a plurality of drilling 1uid circulating pumps are used in a drilling rig ~aving a measurement while drilling apparatus it is necessary to provide a plurality of cascaded pump noise filtering devices in order to selectively remove the noise or pressure and velocity pulsa-tion influence of these specific pumps.
Fig~ 5 illustrates in schematic block diagram form such a pump noise filtering apparatus which is representative of that which could be utilized to filter the pump noise or interference in the pressure pulse data for a drilling rig having two or more drilling fluid circulating pumps. The circuit shown in Fig. 5 includes a pressure sensor 60 a velocity sensor 61a and an associatecl combiner circuit 63 adapted to sense the pressure signaL
data on a drilling rig in khe drilling fluid flow conduit at a point betwe~n the location where fluid Elow Erom the plurality of mud p~p flow conduits merga and the location w~ere this combined flow passes into the drill string. This circuit is sllown with a pair of drilling fluid circulating pumps identified as a first pump 62 and a second pump 64.
In this circuit the effect of the first pump 62 is first removed from the data signal then the effect of the second pump 64 is removed from -the data signal. The first pump 62 is provided with a pump stroke counter circuit that provides pump stroke timing signals to first timing circuit 66. Data from firs-t timing circuit 66 and the drilling fluid pressure signal data from combiner circuit 63 are supplied to a first adaptive memory 68. ~his fluid pressure data signal is supplied as an input to first adaptive es-timator circuit 68. The output from first adaptive estimator 68 is supplied to a first subtraction circuit 70 along wi-th the pressure sensor signal from combiner circuit 63. The output from first subtraction circuit 70 is essentially th~ pressure signal data of the pressure and velocity com~inr circuit 63 with the effect of the first pump 62 removed therefrom.
This data provides the input to the following portion of the circuit that eliminates or filters the effect of the second pump 64.
Second pump 64 is provided with a pump stroke counter circuit the output of which provides sequential pump stroke data to the input of second timing circuit 72. The output from second t~ming circui-t 72 is to one input of second adaptive estimator 74 along with an input from first subtraction circuit 70. ~he output of second adaptive estimator 74 is coupled to one input of second subtraction circuit 76. An output from first subtraction circuit 70 is provided to second subtraction circuit 76. The ou~put from second subtraction circuit 76 has the effect of pressure and velocity pulse interEerence from both pumps 62 and 64 removed or ~iltered from the data and this data is supplied to comparator 78 for comparison with a preselected range of values as described above. The output from comparator 78 is to a data receiver, processor and display essen-tiaLly as described in the preceding embodiment.
In the use and operation of the pump noise flltering apparatus of this invention, i-t is seen -that the same provides a combination of apparatus and circuitry for substantially removing the noise or interference caused by a drilling rig's well drilling fluid circulating pump into the data communication medium for a pressure pulse modulated type syst~m of communication in a measurement while drilling system. This invention is operable with mud pressure modulated communication systems utilizing positive or negative signal pressures and continuous wave or pulse modulation. Although this invention is described wi~ a pressure pulse modulat~d data transmission system it ;s to be understood that it is equally operable with other modulation systems. ~ecause of the adaptive estimator this apparatus will adapt itself to the particular pump and pump noise environment of a particular drilling rig. Also since t,he form of memory used in the adaptive estima-tor can be either an analog form or a digital form depending upon the equipment choice of the user. Thig apparatus can be used with installations having a single pump or installations having multiple pump5. Because the adaptive estimator is sequenced with the strokes of the associated pump it is in effect tuned to memorize representations of the data signal spectrum in which the pressure data signal i5 contained.
Thus, when the memorized signal is removed from the entire spectrum in a selective manner coordinated with the pump strokes it is adapted to remove a representation of the noise due to the pump. Because this particular noise is the major contributor to noise or interference in this pressure medium it removes the undesirable portions of the pressure pulse data signal -thereby in effect filtering the da-ta signal so tha-t it can be easily and accurately converted to a usable digital or analog form compatible with the measurement while drilling systems processing and recording equipment.
~lthough specific preferred embodiments oE this invention have been described in detail in the preceding description. rrhis description is not intended -to limit the invention to the particular form or embodiments disclosed h~rein since they are to be recognized as illustrative rather than restrictive and it would be obvious to -those skilled in the art that the invention is not so limited.
For example, the described analog memory could be a digital memory provided with appropriate analog to di~ital conversion circuitry. ALso provided that a digital memory is used the conversion from an analog signal to a digital signal could be made at the pressure and veloci-ty sensors and at the pump sensor if desired.
Thus the invention is declared to cover all changes and modifications of the specific example of the invention herein disclosed for purposes of illustration 7~3 which does not constitute departures ~rom the spirit and scope of the invention.
Claims (14)
1. In a borehole measurement while driling system for passing data in the form of a modulated data signal stream through drilling fluid in a drill string, a circuit means for substantially removing interferring pressure pulsations caused by a drilling rig's driling fluid circulating pump from the data stream comprising:
(a) means for generating a first signal responsive to the repetitive strokes of a drilling fluid circulating pump;
(b) means for generating a second signal responsive to fluid pressure in a drilling fluid medium that is carrying a pulsed data stream and has pressure pulses from a drilling fluid circulating pump:
(c) means for generating a third signal responsive to fluid velocity in said drilling fluid medium that is carrying a pulsed data stream;
(d) a signal combiner means, coupled to receive said second signal and third signal and operably continuously subtract said third signal from said second signal thereby providing an enhanced second signal as a resultant signal;
(e) an adaptive estimator means adapted to receive said first signal and said second signal and retain as a stored signal a long term average representation of said second signal in a sequence coordinated with said first signal and strokes of said pump;
(f) a subtraction means coupled to said adaptive estimator means and said means for generating a second signal and operable to receive said second signal for subtracting said stored signal from said second signal in a sequence related to the strokes of said pump such that a resultant signal is produced that is representative of the data signal of the borehole measurement while drilling system that was introduced into the drilling fluid.
(a) means for generating a first signal responsive to the repetitive strokes of a drilling fluid circulating pump;
(b) means for generating a second signal responsive to fluid pressure in a drilling fluid medium that is carrying a pulsed data stream and has pressure pulses from a drilling fluid circulating pump:
(c) means for generating a third signal responsive to fluid velocity in said drilling fluid medium that is carrying a pulsed data stream;
(d) a signal combiner means, coupled to receive said second signal and third signal and operably continuously subtract said third signal from said second signal thereby providing an enhanced second signal as a resultant signal;
(e) an adaptive estimator means adapted to receive said first signal and said second signal and retain as a stored signal a long term average representation of said second signal in a sequence coordinated with said first signal and strokes of said pump;
(f) a subtraction means coupled to said adaptive estimator means and said means for generating a second signal and operable to receive said second signal for subtracting said stored signal from said second signal in a sequence related to the strokes of said pump such that a resultant signal is produced that is representative of the data signal of the borehole measurement while drilling system that was introduced into the drilling fluid.
2. The circuit means of claim 1 wherein:
(a) said means for generating a first signal has a pulse generator operable to produce a timing pulse signal indicative of a repetitively reoccurring event correlated to the strokes of a drilling fluid circulating pump; and (b) said subtraction circuit has an inverting circuit connected to receive said stored signals from said adaptive estimator means and an adder circuit to combine signals from said inverting circuit with said second signals in order to arrive at said resultant signal.
(a) said means for generating a first signal has a pulse generator operable to produce a timing pulse signal indicative of a repetitively reoccurring event correlated to the strokes of a drilling fluid circulating pump; and (b) said subtraction circuit has an inverting circuit connected to receive said stored signals from said adaptive estimator means and an adder circuit to combine signals from said inverting circuit with said second signals in order to arrive at said resultant signal.
3. The circuit means of claim 1, additionally including a comparator means receiving said resultant signal and operable to compare it with a predetermined value in order to selectively provide a filtered output signal indicative of said pulsed data signal.
4. The circuit means of claim 1, wherein said adaptive estimator means comprises a tracking commutative filter having an analog memory means adapted to receive portions of said enhanced second signal as an analog signal during discrete time intervals correlated with said first signal during repetitive strokes of said pump in order to retain a representation of said enhanced second signals to make them available for sampling at later time intervals.
5. The circuit means of claim 4, wherein said analog memory means has a multiplexing means connected to a plurality of capacitors and operable to permit sequential selectively charging said capacitors to values corresponding with values of said enhanced second signal occurring during said discrete time intervals.
6. The circuit means of claim 1, wherein said adaptive estimator comprises a tracking commutative filter having a digital memory means adapted to receive said first signal and said second signal and operable in a digital format toretain as said stored signal a representation of said second signal occurring during discrete time intervals correlated with said first signal in order to provide an output signal for said subtraction means.
7. The circuit means of claim 6, wherein said subtraction means has means to receive said second signal and produce a digital representation thereof and means to subtract said stored signal from said digital representation of said second signal in correspondence with said repetitive pump strokes such that said resultant signal is produced in a digital format.
8. The circuit means of claim 7, wherein said subtraction means has means to subtract said memory stored signal from said digital representation of said second signal during selected time segments in correspondence with said pump strokes in order to produce said resultant signal.
9. In a borehole measurement while drilling system for passing data signals in the form of a modulated data signal through drilling fluid in a drill string a circuit means for removing interferring noise from the data signal that is generated by a plurality of borehole drilling fluid circulating pumps, comprising:
(a) a plurality of means for generating a plurality of first signals each being responsive to the individual repetitive strokes of separate drilling fluid circulating pumps of said plurality of pumps;
(b) means for generating a second signal responsive to fluid pressure in a drilling fluid medium carrying a pulsed data signal and also interferring noise pressure pulses from said plurality of drilling fluids circulating pumps;
(c) means for generating a third signal responsive to fluid velocity in said drilling fluid medium that is carrying a pulsed data stream;
(d) a signal combiner means coupled to receive said second signal and said third signal and operably continuously subtract said third signal from said second signal thereby providing an enhanced second signal as a resultant signal;
(e) a plurality of adaptive estimator means with each being associated with said means for generating said first signal and each being adapted to receive the associated first signal and to receive another data signal, to retain a representation of said other data signals in a sequence coordinated with strokes of the associated pump as identified by said associated first signals, and to provide a retained signal;
(f) a plurality of subtraction means, each being associated with an adaptive estimator means, coupled thereto to receive said retained signal, and each receiving said data signal such that subtraction of said retained signal may be subtracted from said data signal in a sequence related to the strokes of said associated pump such that a resultant signal is generated that has the influence of said associated pump removed therefrom; and (g) the associated combination of an adaptive estimator means and a subtraction means are arranged in a cascading manner to one another wherein each associated said adaptive estimator means and said subtraction means are cooperatively operable with an associated pump to filter the influence of that pump from the data signal prior to providing the produced, retained signal to the subsequent associated adaptive estimator means and subtraction means, and further wherein the data signal supplied to the first of said adaptive estimators is said second enhanced signal and the signal of the last subtraction means is a composite data signal representative of the data signals that are placed in the drill string by measurement while drilling apparatus operably connected to the drill string.
(a) a plurality of means for generating a plurality of first signals each being responsive to the individual repetitive strokes of separate drilling fluid circulating pumps of said plurality of pumps;
(b) means for generating a second signal responsive to fluid pressure in a drilling fluid medium carrying a pulsed data signal and also interferring noise pressure pulses from said plurality of drilling fluids circulating pumps;
(c) means for generating a third signal responsive to fluid velocity in said drilling fluid medium that is carrying a pulsed data stream;
(d) a signal combiner means coupled to receive said second signal and said third signal and operably continuously subtract said third signal from said second signal thereby providing an enhanced second signal as a resultant signal;
(e) a plurality of adaptive estimator means with each being associated with said means for generating said first signal and each being adapted to receive the associated first signal and to receive another data signal, to retain a representation of said other data signals in a sequence coordinated with strokes of the associated pump as identified by said associated first signals, and to provide a retained signal;
(f) a plurality of subtraction means, each being associated with an adaptive estimator means, coupled thereto to receive said retained signal, and each receiving said data signal such that subtraction of said retained signal may be subtracted from said data signal in a sequence related to the strokes of said associated pump such that a resultant signal is generated that has the influence of said associated pump removed therefrom; and (g) the associated combination of an adaptive estimator means and a subtraction means are arranged in a cascading manner to one another wherein each associated said adaptive estimator means and said subtraction means are cooperatively operable with an associated pump to filter the influence of that pump from the data signal prior to providing the produced, retained signal to the subsequent associated adaptive estimator means and subtraction means, and further wherein the data signal supplied to the first of said adaptive estimators is said second enhanced signal and the signal of the last subtraction means is a composite data signal representative of the data signals that are placed in the drill string by measurement while drilling apparatus operably connected to the drill string.
10. In a borehole measurement while drilling system for passing data signals in the form of a modulated data signal through drilling fluid in a drill string, a circuit means for removing inteferring noise from the data signal that is caused by a plurality of borehole drilling fluid circulating pumps, comprising:
(a) means for generating a plurality of first signals each being responsive to the repetitive strokes of separate drilling fluid circulating pumps;
(b) means for generating a second signal responsive to fluid pressure in a drilling fluid medium carrying a modulated data stream and including interferring noise pressure pulses from said plurality of drilling fluids circulating pumps;
(c) means for generating a third signal responsive to fluid velocity in said drilling fluid medium that is carrying a pulsed data stream;
(d) a signal combiner means coupled to receive said second signal and said third signal and operably continuously subtract said third signal from said second signal thereby providing an enhanced second signal as a resultant signal;
(e) a first adaptive estimation means associated with one of said means for generating said first signal and being adapted to receive said associated first signal and receive said enhanced second signal and retain a representation of said enhanced second signals in a sequence coordinated with the associated said first signals and strokes of a first associated pump;
(f) a first subtraction means, associated with said adaptive estimator means, coupled thereto and receiving said enhanced second signal such that subtraction of said retained representation of said second signal may be subtracted from said enhanced second signal in a sequence related to the strokes of said associated pump such that a first resultant signal is produced that has the interferring noise influence of said associated pump removed substantially therefrom;
(g) another adaptive estimator means associated with another of said drilling fluid circulating pumps and its associated means for generating said first signal and being adapted to receive said associated first signal and said enhanced second signal and retain another representation of said enhanced second signal in coordination with the associated said first signals and strokes of the associated pump;
(h) another subtraction means associated with said another adaptive estimator means, coupled thereto and also receiving said enhanced second signal such that subtraction of said other retained representation of said enhanced second signal may be subtracted from said enhanced second signal in a sequence related to strokes of said other pump such that an enhanced second resultant signal is produced that has the interferring noise influence of said first associated pump and said other associated pump substantially removed therefrom; and (i) a comparator means connected to receive said enhanced second resultant signal and compare such with predetermined characteristics in order to determine if said enhanced second resultant signal is within such characteristics and generate an output signal correlated to said enhanced second resultant signals having such characteristics.
(a) means for generating a plurality of first signals each being responsive to the repetitive strokes of separate drilling fluid circulating pumps;
(b) means for generating a second signal responsive to fluid pressure in a drilling fluid medium carrying a modulated data stream and including interferring noise pressure pulses from said plurality of drilling fluids circulating pumps;
(c) means for generating a third signal responsive to fluid velocity in said drilling fluid medium that is carrying a pulsed data stream;
(d) a signal combiner means coupled to receive said second signal and said third signal and operably continuously subtract said third signal from said second signal thereby providing an enhanced second signal as a resultant signal;
(e) a first adaptive estimation means associated with one of said means for generating said first signal and being adapted to receive said associated first signal and receive said enhanced second signal and retain a representation of said enhanced second signals in a sequence coordinated with the associated said first signals and strokes of a first associated pump;
(f) a first subtraction means, associated with said adaptive estimator means, coupled thereto and receiving said enhanced second signal such that subtraction of said retained representation of said second signal may be subtracted from said enhanced second signal in a sequence related to the strokes of said associated pump such that a first resultant signal is produced that has the interferring noise influence of said associated pump removed substantially therefrom;
(g) another adaptive estimator means associated with another of said drilling fluid circulating pumps and its associated means for generating said first signal and being adapted to receive said associated first signal and said enhanced second signal and retain another representation of said enhanced second signal in coordination with the associated said first signals and strokes of the associated pump;
(h) another subtraction means associated with said another adaptive estimator means, coupled thereto and also receiving said enhanced second signal such that subtraction of said other retained representation of said enhanced second signal may be subtracted from said enhanced second signal in a sequence related to strokes of said other pump such that an enhanced second resultant signal is produced that has the interferring noise influence of said first associated pump and said other associated pump substantially removed therefrom; and (i) a comparator means connected to receive said enhanced second resultant signal and compare such with predetermined characteristics in order to determine if said enhanced second resultant signal is within such characteristics and generate an output signal correlated to said enhanced second resultant signals having such characteristics.
11. In a borehole measurement while drilling system for a drilling rig with a drill fluid circulating pump, comprising:
(a) a sensor in a drill string adapted to sense a geophysical parameter in a borehole and produce a data signal representative of the sensed physical parameter;
(b) a transmitter for transmitting a representation of said data signal as a transmitted data signal through a drilling fluid in the drill string in a fluid pressure modulated data transmission format;
(c) a receiver at the earth's surface for receiving said transmitted data signal through a pressure transducer in fluid communication with drilling fluid in said drill string and producing an output representative of the data signal of said sensor and also representative of said sensed physical parameter;
(d) said receiver having a filter means therein adapted to remove from said transmitted data signal the pressure pulse influence of said drilling fluid circulating pump such that said transmitted data signals may be recovered without such interference;
(e) said filter means includes, a timing circuit means for sensing strokes of said pump and producing a timing signal representative thereof, a signal combiner means coupled to said pressure transducer and said velocity transducer and operable to combine the signals from said transducers into an enhanced pressure data representative signal, an adaptive estimator means receiving said timing signal and said enhanced pressure data signal from said signal combiner means and operable to temporarily store same data signal in correlation with said timing signal and to produce an output signal in correlation with said timing signal that is representative of an extended term relation to said enhanced pressure data signal, a subtraction means operable to receive said enhanced pressure data signal and selectively remove therefrom said adaptive estimator output signal in correlation with said timing signal in order to reproduce said composite data signal representative of the data signal of said sensor; and a comparator means receiving said composite data signal and having means to compare that data signal with a predetermined value and determine if said composite data signal is within predetermined value limits and produce therefrom an output data signal representative of the data signal of said sensor and related to the sensed geophysical parameter.
(a) a sensor in a drill string adapted to sense a geophysical parameter in a borehole and produce a data signal representative of the sensed physical parameter;
(b) a transmitter for transmitting a representation of said data signal as a transmitted data signal through a drilling fluid in the drill string in a fluid pressure modulated data transmission format;
(c) a receiver at the earth's surface for receiving said transmitted data signal through a pressure transducer in fluid communication with drilling fluid in said drill string and producing an output representative of the data signal of said sensor and also representative of said sensed physical parameter;
(d) said receiver having a filter means therein adapted to remove from said transmitted data signal the pressure pulse influence of said drilling fluid circulating pump such that said transmitted data signals may be recovered without such interference;
(e) said filter means includes, a timing circuit means for sensing strokes of said pump and producing a timing signal representative thereof, a signal combiner means coupled to said pressure transducer and said velocity transducer and operable to combine the signals from said transducers into an enhanced pressure data representative signal, an adaptive estimator means receiving said timing signal and said enhanced pressure data signal from said signal combiner means and operable to temporarily store same data signal in correlation with said timing signal and to produce an output signal in correlation with said timing signal that is representative of an extended term relation to said enhanced pressure data signal, a subtraction means operable to receive said enhanced pressure data signal and selectively remove therefrom said adaptive estimator output signal in correlation with said timing signal in order to reproduce said composite data signal representative of the data signal of said sensor; and a comparator means receiving said composite data signal and having means to compare that data signal with a predetermined value and determine if said composite data signal is within predetermined value limits and produce therefrom an output data signal representative of the data signal of said sensor and related to the sensed geophysical parameter.
12. The borehole measurement while drilling system of claim 11, wherein:
(a) said timing circuit means timing signal is representative of the stroke rate of the associated drilling fluid circulating pump and a plurality of segment divisions thereof;
(b) said adaptive estimator means includes a memory means operable to store a representation of said enhanced pressure data signal in a plurality of designated data segments corresponding with said plurality of segmented divisions of said timing signal and further operable to provide access to such stored representations of said enhanced pressure data signal.
(a) said timing circuit means timing signal is representative of the stroke rate of the associated drilling fluid circulating pump and a plurality of segment divisions thereof;
(b) said adaptive estimator means includes a memory means operable to store a representation of said enhanced pressure data signal in a plurality of designated data segments corresponding with said plurality of segmented divisions of said timing signal and further operable to provide access to such stored representations of said enhanced pressure data signal.
13. The borehole measurement while drilling system of claim 11, wherein said adaptive estimator means has a tracking commutative filter means operable to receive said timing signal and said enhanced pressure data signal and to provide a filtered output signal for said subtraction means.
14. The borehole measurement while drilling system of claim 11, wherein said transmitter for said data signal uses pulse modulation to modulate the data signal for transmission in the drilling fluid.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US31949981A | 1981-11-09 | 1981-11-09 | |
| US319,499 | 1989-03-06 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1188979A true CA1188979A (en) | 1985-06-18 |
Family
ID=23242495
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000411960A Expired CA1188979A (en) | 1981-11-09 | 1982-09-22 | Pump noise filtering apparatus for a borehole measurement while drilling system utilizing drilling fluid pressure sensing and drilling fluid velocity sensing |
Country Status (4)
| Country | Link |
|---|---|
| EP (1) | EP0078906A3 (en) |
| JP (1) | JPS5886296A (en) |
| CA (1) | CA1188979A (en) |
| NO (1) | NO823380L (en) |
Families Citing this family (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| DE3428931C1 (en) * | 1984-08-06 | 1985-06-05 | Norton Christensen, Inc., Salt Lake City, Utah | Device for the remote transmission of information from a borehole to the surface of the earth during the operation of a drilling rig |
| US5146433A (en) * | 1991-10-02 | 1992-09-08 | Anadrill, Inc. | Mud pump noise cancellation system and method |
| US20030228333A1 (en) * | 2002-05-28 | 2003-12-11 | Fecht Cassandre Michelle | Substituted hydrocarbyl functional siloxanes for household, health, and personal care applications |
| US8004421B2 (en) | 2006-05-10 | 2011-08-23 | Schlumberger Technology Corporation | Wellbore telemetry and noise cancellation systems and method for the same |
| US8629782B2 (en) | 2006-05-10 | 2014-01-14 | Schlumberger Technology Corporation | System and method for using dual telemetry |
| US9958849B2 (en) * | 2013-02-20 | 2018-05-01 | Schlumberger Technology Corporation | Cement data telemetry via drill string |
| CA2966729A1 (en) | 2014-12-05 | 2016-06-09 | Halliburton Energy Services, Inc. | Downhole clock calibration apparatus, systems, and methods |
| BR112017009719A2 (en) | 2014-12-10 | 2018-02-20 | Halliburton Energy Services Inc | method and apparatus for telemetry schemes used in oil and gas exploration and extraction. |
| CN115573695B (en) * | 2022-09-14 | 2024-04-26 | 成远矿业开发股份有限公司 | Automatic acquisition method and system for effective drilling data of drilling machine |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3714623A (en) * | 1971-06-08 | 1973-01-30 | Schlumberger Technology Corp | Memorizer |
| US4093923A (en) * | 1976-12-22 | 1978-06-06 | Shell Oil Company | Signal cancelling circuit |
| CA1124228A (en) * | 1977-12-05 | 1982-05-25 | Serge A. Scherbatskoy | Systems, apparatus and methods for measuring while drilling |
| GB2076968B (en) * | 1980-05-27 | 1984-08-15 | Dresser Ind | Fluid pressure pulse detection apparatus |
-
1982
- 1982-09-22 CA CA000411960A patent/CA1188979A/en not_active Expired
- 1982-09-23 EP EP82108792A patent/EP0078906A3/en not_active Withdrawn
- 1982-10-08 NO NO823380A patent/NO823380L/en unknown
- 1982-11-08 JP JP57195854A patent/JPS5886296A/en active Pending
Also Published As
| Publication number | Publication date |
|---|---|
| NO823380L (en) | 1983-05-10 |
| JPS5886296A (en) | 1983-05-23 |
| EP0078906A3 (en) | 1984-09-12 |
| EP0078906A2 (en) | 1983-05-18 |
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