fig1 a illustrates a general overview of a tool submerged downhole . shown are tool 10 , fluid vent 20 , formation 30 , and well fluid 210 . fluid vent 20 provides a means for well fluid 210 to enter and exit tool 10 . while in tool 10 , well fluid 210 is measured for its acoustic properties . fig1 b is a cross - sectional view of the tool showing acoustic measurement components . inside tool 10 , where fluid vent 20 is located , are acoustic transducer 200 and metal disk 220 . as can be seen , well fluid 210 enters tool 10 , flows between acoustic transducer 200 and metal disk 220 , and exits tool 10 . fig2 illustrates the acoustic wave path and metal disk reverberations for a downhole acoustic wave . shown are acoustic transducer 200 , well fluid 210 and metal disk 220 . well fluid 210 and disk 220 each has its own impedance , labeled z m and z s , respectively . also shown is acoustic signal 250 , including first reflected portion 260 , disk reverberation portions 271 - 276 and transmitted wave portions 280 , 282 , 284 and 286 through the disk in the same well fluid . to measure the reflection coefficient of the well fluid , the acoustic transducer 200 sends out acoustic signal 250 , which is preferably an ultrasonic impulse with a characteristic frequency of about 500 khz , then switches to the receive mode . the impulse frequency is preferably set at the expected resonance frequency of the disk . the acoustic signal 250 travels through the well fluid 210 and strikes the disk 220 . the largest portion of the energy of the impulse is reflected back to the transducer as reflected portion 260 while a small amount of signal enters the disk as wave 280 . when the well fluid 210 is water , the reflected wave form has an amplitude of about 93 % of the initial impulse . the portion of the signal that entered the disk is reflected back and forth between the disk / fluid interface and the disk / tool interface , as illustrated by wave reverberations 271 - 276 . at each reflection some energy is transmitted through the interface , dependent on the acoustic impedance contrast , and is either directed back toward the transducer or out into the tool . the signal inside the disk is quickly dissipated in this manner at a rate directly dependent on the acoustic impedance of the material outside the disk according to the equation : where r 1 is the reflection coefficient , and z 1 and z 2 are the impedances of the materials at the interface in question . in a preferred embodiment , the thickness of the metal disk is set to one half of the resonant wavelength of the transducer signal . the acoustic transducer 200 , now acting as a receiver or transducer , sees a waveform consisting of a loud initial reflection followed by an exponentially decaying reverberation signal . fig3 illustrates the measured acoustic waveform received at the transducer 200 . if time t = 0 is the time of generation of the acoustic wave at the acoustic transmitter , then the time t tran represents the transit time ( the time for the travel of this acoustic wave to the disk and back to the transceiver ). since the distance is fixed , the transit time t tran provides an indication of the acoustic velocity of the fluid . also shown in fig3 are the time offset , t off , and the resonance window , t win , both of whose significance is explained below . fig4 illustrates the individual waveforms , both first reflection and reverberations , that sum to provide the waveform of fig3 . the waveform received by the transducer is the sum of the initial reflection waveform with each reverberation waveform , where each reverberation is delayed an amount proportional to the width of the disk . further , because the acoustic transducer is not a perfect transmitter , it “ rings ” somewhat upon the transmission of an acoustic wave . this transducer “ ringing ” also is included in the detected waveform , and may be accounted for by the present invention . fig5 illustrates a device built in accord with a preferred embodiment . shown in fig5 a is acoustic transducer 200 , analog - to - digital converter 500 , a processor 510 for recording start time and gain , waveform compression chip 520 , and multiplexer 530 . waveform compression chip 520 could alternately be part of a processor . also shown are downhole transmitter 540 connected to multiplexer 530 and telemetry cable 545 . referring now to fig5 b , at the surface are located uphole receiver 550 , demultiplexer 560 , transmission line 564 carrying tool information to processor 590 for a data log 595 , transmission line 570 carrying gain and start time information to uphole processor 590 , and waveform decompression chip 580 . attached to decompression chip 580 is processor 590 . processor 590 generates data suitable for a log 595 . referring now to both fig5 a and 5b , acoustic transducer 200 collects data of metal disk reflection and reverberation . this acoustic waveform is digitized by analog - to - digital converter 500 and sent to processor 510 , which detects the first reflection from the digitized signal . processor 510 then computes the relevant start time and transit time . because the total waveform data may be greater than the bandwidth capacity of transmission line 545 , digital compression 520 is preferably performed . suitable compressions include wavelet and adpcm ( adaptive differential pulse code modulation ) techniques , which work well for smoothly varying data . the compressed waveform from digital compression chip 520 is then multiplexed 530 with the other tool information . downhole transmitter 540 sends this multiplexed data to the surface . sending the data to the surface allows processing by faster , more sophisticated machinery . this multiplexed data is received by uphole receiver 550 and is separated into component parts by demultiplexer 560 . waveform decompression chip 580 provides the reconstructed waveform to processor 590 , which also receives start time information . upon the determination of the reflection coefficient of the well fluid , processor 590 combines with position information and creates a log 595 . fig6 illustrates a general method for the present invention . in block 600 , an observed waveform is provided uphole for processing . in some embodiments , it may be desirable to stack waveforms ( block 610 ). the waveform &# 39 ; s transit time ( t tran ) is obtained in block 620 , as well as the time windows t off and t win . the definition of transit time was explained above with reference to fig3 and may be easily measured by a first reflection detector portion of processor 510 . t off and t win are then selected to obtain a time window t win that contains reliable reverberation information . t off , measured from the time of receipt for the initial reflection , is a time window that encompasses the initial reflection . as such , its duration is dependent upon the duration of the acoustic impulse transmitted by acoustic transducer 200 and the nature of the drilling fluid . t off also preferably accounts for error introduced because of the real - world shortcomings of the acoustic transducer ( transducer “ ringing ”), and thus t off may be slightly longer than if chosen theoretically . nonetheless , t off is about 15 microseconds . t win is juxtaposed with t off and is a time window of interest because t win contains reverberation information uncontaminated by the first reflection . the duration of t win should be brief enough so that noise and reverberations occurring in the tool 10 do not make unreliable the received disk reverberation waveforms . nonetheless , so that a reliable wave train containing sufficient data is obtained , t win preferably includes at least four reverberations . thus , t win is about 12 . 8 microseconds . the tool calibration may be obtained as follows . first , the reflection waveform defined by t off is transformed to the frequency domain by use of dft ( discrete fourier transform ). referring back to fig6 proper modeling applied to the first reflection portion 260 , as defined by t off , gives a theoretical prediction of what the reverberation waveform contained in t win should look like . to accomplish this , in block 630 the first reflection signal is transformed by fast fourier transform ( fft ) into its frequency domain equivalent . this yields s ( ω ). because the modeling is done in the frequency domain , amplitude and phase errors are eliminated . this error elimination simplifies mathematical processing ( and hence faster processing is obtained ). alternately , instead of transforming each first reflection individually , to enhance accuracy , the first reflections from multiple firings may first be averaged and the result transformed in block 630 by fft processing into the frequency domain to yield s ( ω ). a most reliable first reflection average may be obtained by discarding first reflections that have amplitudes above or below a preset deviation from a moving average of preceding first reflections . in block 640 , a theoretical prediction of the reverberation waves is obtained by multiplying ( convolution in time domain ) the frequency - domain first reflection signal s ( ω ) with a frequency - domain theoretical response equation r ( ω ) to obtain a frequency domain version x ( ω ) of the reverberation signal x ( t ). assuming a flat metal disk , the theoretical frequency domain response may be modeled by the following : r  ( ω ) = z m - z s z m + z s + 4  z m  z s  ( z s - z m ) ( z m + z s ) 3 1 - ( z s - z m z m + z s ) 2   -  2   ω   c t v s   -  2   ω   c t v s  ( 2 ) z m , z s ,= impedances for mud and metal disk , respectively v s = the speed of sound in the metal disk , and the above equation assumes that the transducer generates waves having normal ( i . e ., perpendicular ) incidence on the disk . v s , z s , and c t can be measured very precisely as basic physical properties of the metal disk . in block 640 the frequency domain signal x ( ω ) is transformed back into the time domain by use of an inverse fast fourier transform ( ifft ). as such , block 640 provides the theoretical reverberation response x ( t ) for the observed initial reflection waveform ( s ) in the time domain . this theoretical reverberation response is also a function of the borehole fluid impedance z m . once the results are converted to the time domain , a relationship is established between the theoretical response and the received response . next , a method is used to determine the borehole fluid properties in block 650 . two embodiments for relating theoretical and measured responses in block 640 include 1 ) a curve fitting method and 2 ) a non - linear waveform inversion method . both methods calculate theoretical waveform response based on equation 2 . however , the curve fitting method uses fewer theoretical modeling steps than the inversion method . fig7 a illustrates the curve fitting method , where a measurement equation is determined . as an initial matter , for a reverberation window of interest , t win , the natural log of the sum of the reverberation waveform amplitude ( s w ) varies linearly with well fluid impedance . that is , a linear relationship between well fluid impedance and s w may be expressed as : where s w is the sum of the reverberation waveform amplitudes and has the form : s w = ∑ t   x  ( t )  ( 4 ) the lower case x ( t ) being the amplitude at any given point in the reverberation waveform contained in t win . for the curve - fitting method , block 640 includes blocks 700 - 760 . in block 700 , an initial theoretical fluid impedance z m is chosen . in block 710 , the theoretical response r ( ω ) is calculated in accordance with equation 2 . in block 720 , the first reflection is convolved with the theoretical response obtained in block 710 . in block 730 , the inverse fast fourier transform ( ifft ) is performed to obtain a theoretical reverberation waveform . next , the summed amplitudes of the theoretical reverberation waveform s w is determined in block 740 . in block 750 , the theoretical response r ( ω ) and reverberation waveform amplitude sum s w are stored . in block 760 , it is decided whether or not additional data is needed . if additional data is necessary , another theoretical fluid impedance z m may be chosen in block 700 . to determine the coefficients in this linear relationship , steps 700 - 760 are repeated at least twice for different assumed fluid impedances z m . each time , the resulting sum s w is calculated . from these multiple points , ( s w , z m ), the coefficients a , b , can be determined using the least squares curve fitting in block 770 . with the relationship , the measured impedance z m can be determined from the observed s w using equation 4 in block 780 . lastly , in block 650 ( fig6 ), s w is substituted into equation 3 , and well fluid impedance z m is determined . the acoustic velocity of the fluid may also be calculated in block 650 . because the separation between the transducer and disk is known , the velocity is calculable from the measured transit time t tran . from the impedance ( ρ ) and velocity ( v ), the fluid density ( z m ) can be calculated due to the relationship : z m = ρv . as mentioned above , in a second embodiment , non - linear waveform inversion may be used in block 640 to determine the relationship between theoretical and measured reverberation . while the waveform inversion method is slower than the curve fitting method described above , it produces more accurate results because it matches entire reverberation waveform window using both amplitude and phase . as a result , many fluid acoustic properties including density and attenuation can be calculated simultaneously . a preferred method employs the levenberg - marquardt method . see generally w . press et al ., levenberg - marquardt method , p . 542 ( numerical recipes in c , 1988 ). in the non - linear waveform inversion embodiment shown in fig7 b , fluid properties such as velocity , density , and attenuation are initially estimated in block 800 . in block 810 , the theoretical response r ( ω ) is calculated in accordance with equation 2 . in block 820 , the first reflection is convolved with the theoretical response obtained in block 710 . in block 830 , the inverse fast fourier transform ( ifft ) is performed to obtain an estimated reverberation waveform . in block 840 , the error between the estimated and measured waveforms is determined . the error is calculated according to equation 5 . error = σ   ( observed - theoretical ) 2   ( 5 ) in block 850 , the error calculated in block 840 is compared to a predetermined tolerance . if the calculated error is greater that the predetermined tolerance , another estimate is performed in block 800 using the levenberg - marquardt method . this cycle is repeated until the calculated error is less than the predetermined tolerance . when the calculated error is less than the predetermined tolerance , the estimated fluid velocity , density , and attenuation are accepted as the measured properties in block 860 . while preferred embodiments of this invention have been shown and described , modifications thereof can be made by one skilled in the art without departing from the spirit or teaching of this invention . the embodiments described herein are exemplary only and are not limiting . for example , while the present invention has been described for use while drilling a well , it may also be used during completing and producing . many variations and modifications of the system and apparatus are possible and are within the scope of the invention . accordingly , the scope of protection is not limited to the embodiments described herein , but is only limited by the claims that follow , the scope of which shall include all equivalents of the subject matter of the claims .