US20160139085A1 - Apparatus and method for analysis of a fluid sample - Google Patents

Abstract

An method for analyzing a fluid comprises collecting a sample of the fluid and exposing the fluid sample to a light of a predetermined wavelength at a predetermined modulation frequency. An acoustic signal caused by the interaction of the light and the fluid sample is sensed, and the sensed acoustic signal is related to at least one component of the fluid.

Description

BACKGROUND OF THE INVENTION
• The present disclosure relates generally to the determination of the composition of a fluid sample. More specifically, the present disclosure relates to the determination of the composition of a multi-component fluid using detected acoustical signals related to the various components of the fluid sample.
• It is of interest to know the both composition and concentration of materials in a fluid extracted from a reservoir or a fluid stream. In the case of reservoirs, the analysis may comprise extracting fluid from the native formation by pumping with a formation test tool, flowing the well in a drill stem test or examining the drill cuttings circulated to surface during drilling. The examination of the samples may be accomplished by transporting a quantity of the fluids to a laboratory and the separating the fluid into its constituent parts by distillation and/or by chromatographic methods. Another method relies on the measurement of light transmitted through a sample. This approach places a windowed cell within the fluid flow path of a formation testing tool. In one example, this method may require the determination of the amount of power delivered to the sample and the amount of power that is transmitted through the sample. The care and maintenance of the optical receiver can be difficult. High downhole temperatures can adversely affect a photodiode used as a receiver.
BRIEF DESCRIPTION OF THE DRAWINGS
• A better understanding of the present disclosure can be obtained when the following detailed description of example embodiments are considered in conjunction with the following drawings, in which:
• FIG. 1 shows a schematic of one example of a fluid analysis apparatus;
• FIG. 2 shows a schematic of another example of a fluid analysis apparatus;
• FIG. 3 is a partial sectional view of a formation testing tool having a fluid analysis apparatus;
• FIG. 4 is a schematic of a fractionating process including a fluid analysis apparatus;
• FIG. 5 shows one example of the overlapping relationship of a chopper wheel and a filter arrangement;
• FIG. 6 shows a well drilling system comprising a bottom hole assembly that includes a formation testing tool; and
• FIG. 7 shows an enlarged view of the formation testing tool ofFIG. 6.
• While the invention is susceptible to various modifications and alternative forms, specific embodiments thereof are shown by way of example in the drawings and will herein be described in detail. It should be understood, however, that the drawings and detailed description thereto are not intended to limit the invention to the particular form disclosed, but on the contrary, the intention is to cover all modifications, equivalents and alternatives falling within the scope of the present disclosure as defined by the appended claims.
DETAILED DESCRIPTION
• Photoacoustic spectroscopy (PAS) is based on the absorption of light energy by a molecule. The signal in PAS is monitored by acoustic detection. Photoacoustic spectroscopic detection is based on the generation of acoustic waves as a consequence of light absorption. Absorption of light by a sample exposed thereto excites molecules in the sample. Modulation of the light intensity (turning the light on and off as the sample is exposed) causes the temperature of the sample to rise and fall with the absorption profile of the sample. As used herein, light refers to electromagnetic radiation of all wavelengths, whether visible or not. The temperature variation of the sample is accompanied by a pressure variation that creates a sound wave. The sound wave can be detected with an acoustic detector, for example a microphone. Many of the components of oil reservoir fluids have absorption bands in the infrared portion of the electromagnetic spectrum. By exciting the component with energy having a wavelength in the appropriate absorption band, the component can be caused to generate a sound signal which is indicative of the component. For gases, many of the absorption wavelengths are in the infrared portion of the electromagnetic spectrum. For example, the absorption wavelengths for hydrocarbon gases including methane, propane, and butane are in the range of 1677 nm and 1725 nm. Hydrogen sulfide gas has a group of absorption wavelengths near 1578 nm and carbon dioxide has several absorption wavelengths near 2007 nm and 1572 nm. It is to be noted that liquids may exhibit photoacoustic signal generation similar to, but possibly smaller in amplitude to, that of gases.
• FIG. 1 shows a schematic of one example of ananalysis apparatus100 for determining the components of a fluid sample. As used herein, the term fluid is used to mean a gas, a liquid, and a combination of a gas and a liquid. In the example ofFIG. 1, a fluid flowing ininlet line124 is admitted tosample chamber115 throughvalve126 and sealed off byclosing valves126 and128.Sample chamber115 comprises anoptical window116 through at least a portion of one wall ofsample chamber115.Acoustic detector117 may be inserted through the wall ofsample chamber115 andcontact sample fluid114.Acoustic detector117 may comprise a capacitance microphone, a piezoelectric sensor, or any other suitable acoustic signal detector.Pump122 is connected tosample chamber115. In oneembodiment pump122 is a positive displacement pump. Positive displacement pumps include, but are not limited to, gear pumps and piston pumps. In one example,pump122 may be activated to lower the pressure insample chamber115 below the vapor pressure of the fluid components such that substantially all of the original sample is converted to a gas phase.Pump122 may also be used to pressure tune the acoustic response for enhanced signal generation. In one example,heater118 may be attached tosample chamber115 to raise the temperature ofsample chamber115 andsample114 to assist in converting any liquid insample chamber115 to a gas phase. In another example, temperature may be used to pressure tune the photo acoustic response. In yet another example, the combination of a temperature tunable phase change substance with a temperature controlled cold element, both in operative contact withsample chamber115, may be used to pressure tune the photo acoustic response. In one embodiment, the photo acoustic response of the phase change substance may serve as an internal reference standard.
• In one embodiment, a light system101 compriseslight source104,mirror102,chopper wheel106, andfilter wheel108. In one example,light source104 may be a broad band infra-red source such as a heated filament wire. The energy fromlight source104 may be collected and reflected bymirror102 towardsample chamber115. In one example, a focusing element (not shown) may be used to localize the energy within thesample114 such that the intensity of the interaction is sufficient to generate a large temperature differential with respect to the surrounding fluid thereby allowing a large pressure gradient to form. The amplitude of the generated acoustic signal is related to the generated pressure gradient.
• A motor (not shown) may drivechopper wheel106 at a predetermined rate to modulate the light passed tosample114 at a predetermined frequency, f Rings R₁and R₂ofslots150 and151 may be formed inchopper wheel106. The length and spacing of the slots in each individual ring may be different, such that the duty cycle (frequency and duration) of the energy transmitted to heat thesample fluid114 may be different throughslots150 as compared to the energy transmitted to heat thesample fluid114 throughslots151. Any suitable number of rings Ri may be formed inchopper wheel106. The sample is heated by the absorption of the energy fromlight source104 during the exposed time. In contrast, when choppingwheel106 block the energy, thesample114 cools off. Afilter wheel108 may comprise several filters110_ithat allow passage of a predetermined wavelength λ_iof the energy fromsource104 that interacts with a component C_iofsample114. Alternatively, an electronic or mechanical shutter, or series of shutters, may be used instead of a chopper wheel. The heating and cooling ofsample114 generates pressure fluctuations that are related to the presence of component C_iinsample114. In one example, seeFIG. 1,filter wheel108 is rotatable such that one filter component110_iis optically aligned to allow energy of wavelength λ_ito interact withsample114 at a first time interval.Filter wheel108 may then turned to allow a different to interact withsample114 at a second time interval.
• In another example, seeFIG. 5, filter wheel508 is shown overlayingchopper wheel106. Filters110_imay be arranged radially such that each filter passes a different characteristic wavelength, λ_i, interacting with a different ring Ri of slots150-153. Energy may be transmitted from all of the filters simultaneously to sample114. The heating and cooling from each ring of slots will have a characteristic frequency, f_i, related to the number and spacing of the slots in each ring, and the rotational speed of the chopper wheel. The various energy absorbing components ofsample114 will emit multiple acoustic frequencies related to the appropriate filter and slot interaction. Multiple components C_ican be simultaneously identified. For example, energy of wavelengths λ₁and λ₂, associated with rings R₁and R₂, may be transmitted at frequencies f₁and f₂to interact withsample114. Frequencies λ₁and λ₂are determined by the number of slots in rings R₁and R₂and the rotational rate of thechopper wheel106. Ifsample114 contains components C₁and C₂, associated with wavelengths λ₁and λ₂, thesample114 will emit acoustic signals at frequencies f₁and f₂. If, in another example, only component C₁is present, then sample114 will emit an acoustic signal at frequency f₁, but not at frequency f₂.
• Controller132 may compriseelectronic circuits134, aprocessor136, and amemory138 in data communication withprocessor136.Electronic circuits134 may interface with and supply power tolight source104,heater118,acoustic detector117, and pump122.Processor136 may comprise a single processor or multiple processors, including a digital signal processor. Programmed instructions may be stored inmemory138 that when executed byprocessor136, controls the operation ofanalysis apparatus100. In one example,electronic circuits134 may comprise analog filters to detect signals at the predetermined frequencies discussed previously. Alternatively, the sensor signal may be digitized and analyzed digitally for signals at the predetermined frequencies using techniques known in the art. In addition, data and models may be stored inmemory138 that relates the acoustic signal to the components C_i. For example, data relating to the specific absorption wavelengths may be stored inmemory138 for use in identifying the components ofsample114. In one example, data may be transmitted fromcontroller132 bytelemetry device140 to anexternal controller142 for further data analysis and correlation. Alternatively, data may be stored on a computerreadable medium141 that may comprise a hard disk, a flash memory, a CD, a DVD, or any other suitable computer readable medium.
• In another embodiment,FIG. 2 shows a schematic of one example of ananalysis apparatus200 for determining the components of a fluid sample. A fluid flowing ininlet line224 is admitted to samplechamber215 throughvalve226, and sealed off by closingvalves226 and228.Sample chamber215 may compriseoptical windows216 and219 through the walls ofsample chamber215.Acoustic detector217 may be inserted through the wall ofsample chamber215 andcontacts sample fluid214.Pump222 is connected to samplechamber215. Pump222 may be a positive displacement pump similar to pump122 ofFIG. 1. Positive displacement pumps include, but are not limited to, gear pumps and piston pumps. Pump222 may be activated to lower the pressure insample chamber215 such that substantially all of the original sample is converted to a gas phase. Alternatively, an aliquot of the sample may be introduced into the chamber at reduced pressure with higher, the same, or lower temperature than the original fluid in order to flash the sample to the gas phase. In one example,heater218 may be attached to samplechamber215 to raise the temperature ofsample chamber215 andsample214 to assist in converting any liquid insample chamber215 to a gas phase.
• Light sources244 and242 may be narrow band infrared sources such as a laser, a laser diode, and a tunable laser diode. Each light source may emit a different light wavelength λ_ifor identifying different components C_iofsample214. While shown with two optical energy sources, it is understood that any number of light sources may be employed within the constraints of providing a suitable window access tosample214. Alternatively, optical fibers may be placed and sealed through the wall. In one example, energy may be introduced to the sample using nanofiber evanescent field generation, known in the art.
• Source controllers246 and240 may comprise control circuits for controlling the activation ofsources244 and242 respectively. For example, such circuits may control the on-off frequency and amplitude of each source. This capability allows these types of sources to operate without the need for the mechanical chopper and the filter wheel of the embodiment shown inFIG. 1. The heating and cooling ofsample214 generates pressure fluctuations that are related to the presence of component C_iinsample214.Controller232 may compriseelectronic circuits234, aprocessor236, and amemory238 in data communication withprocessor236.Electronic circuits234 may interface with and supply power tocontroller sources246 and240,heater218,acoustic detector217, and pump222. Thesources242 and244 may be operated simultaneously, at different duty cycles, for simultaneous detection of components C_iofsample214. The electronic control of the sources allowscontroller232 to synchronize the signal detection to the source activation to enhance the signal to noise ratio.Processor236 may comprise a single processor or multiple processors, including a digital signal processor. Programmed instructions may be stored inmemory238 that when executed byprocessor236, controls the operation ofanalysis apparatus200. In addition, data and models may be stored inmemory238 that relates the acoustic signal to the components C_i. For example, data relating to the specific absorption frequencies may be stored inmemory238 for use in identifying the components ofsample214. Alternatively, data may be stored on a computerreadable medium241 that may comprise a hard disk, a flash memory, a CD, a DVD, or any other suitable computer readable medium.
• In one example, still referring toFIG. 2, anelectromagnet250 may be disposed at least partially aroundsample chamber215 for use in detecting oxygen, O₂, insample214. Oxygen does not absorb infrared light. However, by subjectingsample214 to a pulsating magnetic field, the oxygen molecules will start to vibrate generating a pressure change that is detected byacoustic detector217. One skilled in the art will appreciate that a magnetic coil may also be incorporated aroundsample chamber115 ofFIG. 1.
• In one example,FIG. 3 shows aformation testing tool10 for obtaining and analyzing a fluid sample from asubterranean formation12 through awellbore14.Formation testing tool10 is suspended inwellbore14 by awireline cable16 that connects thetool10 to asurface control unit36. Alternatively,formation testing tool10 may be deployed inwellbore14 on coiled tubing, jointed drill pipe, hard wired drill pipe, or any other suitable deployment technique.Formation testing tool10 may comprise an elongated,cylindrical body18 having acontrol module20,fluid acquisition module22, andfluid storage modules24,26.Fluid acquisition module22 comprises an extendablefluid admitting probe32 and extendable tool anchors34. Fluid is drawn into the tool throughprobe32 by a fluid pumping unit (not shown). The acquired fluid then flows throughfluid measurement module200 that, as described above, analyzes the fluid using PAS techniques described herein, and sends data to surfacecontrol unit36 via thewireline cable16. The fluid then can be stored in thefluid storage modules24,26 and retrieved to the surface for further analysis.
• In another example embodiment, referring toFIG. 6, a drilling rig10 (simplified to exclude items not important to this application) comprises aderrick12,derrick floor14, draw works16,hook18,swivel20, kelly joint22 and rotary table24, such components being arranged in a conventional manner so as to support and impart rotation todrillstring26.Drill string26 includes at its lower end abottom hole assembly29 which comprisesdrill collar28, MWD tool30 (which may be any kind of MWD tool, such as an acoustic logging tool), MWD formation testing tool32 (which may be a separate tool as shown or may be incorporated into another tool) anddrill bit34. Drilling fluid (which may also be referred to as “drilling mud”) is injected into the swivel by amud supply line36. The mud travels through the kelly joint22,drillstring26,drill collars28,MWD tool30 and MWDformation testing tool32 and exits through ports in thedrill bit34. The mud then flows up theborehole38. Amud return line40 returns mud from theborehole38 and circulates it to a mud pit (not shown) and ultimately back to themud supply line36.
• The data collected by theMWD tool30 andformation testing tool32 may be returned to the surface for analysis by telemetry transmitted in any conventional manner, including but not limited to mud pulse telemetry, electromagnetic telemetry, and acoustic telemetry. Alternatively,drill string26 anddrill collars28 may be hard wired to provide high data rate telemetry. For purposes of the present application, the embodiment described herein will be explained with respect to use of mud pulse telemetry. Atelemetry transmitter42 located in adrill collar28 or in one of the MWD tools collects data from the MWD tools and transmits it through the mud via pressure pulses generated in the drilling mud. A telemetry sensor44 on the surface detects the telemetry and returns it to ademodulator46. Thedemodulator46 demodulates the data and provides it tocomputing equipment48 where the data is analyzed to extract useful geological information.
• Further, commands may be passed downhole to the MWD tool andformation testing tool32 in a variety of ways. In addition to the methods described in the previous paragraph, information may be transmitted by performing predefined sequences of drill pipe rotations that can be sensed in the MWD tools and translated into commands. Similarly, the mud pumps may be cycled on and off in predefined sequences to transmit information in a similar fashion.
• In one embodiment, theformation testing tool32 comprises a plurality of centralizingpistons60 and one ormore sampling pistons62, as shown inFIG. 7. For present purposes, the formation testing tool will be described with reference totool32 having onesampling piston62, it being understood that the tool could likewise be configured to include additionalsuch pistons62. The plurality of centralizingpistons60 centralize theformation testing tool32 in theborehole38. Once theformation testing tool32 is centralized, thesampling piston62 extends from theformation testing tool32 to theborehole wall66, where it seals against the wall and allows formation testing to be performed.
• In one embodiment of theformation testing tool32, the centralizingpistons60 are all in the same cross section and thesampling piston62 is in a different cross section. In another embodiment, one or more of the centralizingpistons68 are in a different cross-section from the remaining centralizingpistons60. In still another embodiment, the centralizing pistons are in three or more cross sections.
• During drilling operations, the centralizingpistons60 and thesampling piston62 are retained in a retracted position inside theformation testing tool32. In this position, thesampling piston62 is recessed below the surface of theformation testing tool32, as is discussed further below. When it is time to perform the formation testing function, the rotation of thedrill string26 is ceased and the centralizingpistons60 are extended at the same rate so that theformation testing tool32 is relatively centralized within the borehole, as shown inFIG. 7. Thesampling piston62 is then extended and theformation testing tool32 performs its testing function, including analyzing the formation fluid using the PAS techniques described herein. One skilled in the art will appreciate that the above described MWD formation testing tool may be alternatively deployed in the wellbore with coiled tubing equipment (not shown), using techniques known in the art.
• In another example, seeFIG. 4, a process feed stream, which may comprise hydrocarbon components, is fractionated in afractionating apparatus402.Different fractionating components404,406,408 and410 are removed at different levels of the process. Samples of fractionatingcomponents404,406,408 and410 may be taken throughvalves421,422,423 and424. The samples may be analyzed by an analysis system such asanalysis system100 described previously, or alternatively, byanalysis system200 described previously, to determine the components of the individual streams.
• The analysis systems described herein may also be used for analyzing fluid components in pipelines.
• In one operational example, for use with a liquid slurry, the length of the energy pulse may be used to control the depth of investigation into the sample, thereby allowing the examination of the carrier liquid while substantially ignoring the slurry solids. In another example, the lengthening of the ON pulse time may be used to detect fouling of the optical windows. For example, a constant acoustic signal amplitude with an increasing ON pulse length, may indicate that the acoustic signal is not penetrating deeper into the sample but is being generated in a substantially small fluid volume near the window.
• Numerous variations and modifications will become apparent to those skilled in the art. It is intended that the following claims be interpreted to embrace all such variations and modifications.

Claims (6)

What is claimed is:

1. A method for analyzing a fluid comprising:

collecting a sample of the fluid;

exposing the fluid sample to a light of a predetermined wavelength at a predetermined modulation frequency;

sensing an acoustic signal caused by the interaction of the light and the fluid sample; and

relating the sensed acoustic signal to at least one component of the fluid.

2. The method ofclaim 1 wherein collecting a sample of the fluid comprises collecting a sample of a formation fluid with a formation test tool in a well.

3. The method ofclaim 1 wherein exposing the sample to a light of a predetermined wavelength at a predetermined modulation frequency comprises filtering a broadband light into at least one predetermined wavelength and chopping the light into at least one predetermined modulation frequency.

4. The method ofclaim 3 wherein filtering a broadband light into at least one predetermined wavelength and chopping the light into at least one predetermined modulation frequency comprises filtering the light into a plurality of predetermined wavelengths and chopping each of the plurality of wavelengths into a different predetermined modulation frequency.

5. The method ofclaim 4 wherein relating the sensed acoustic signal to at least one component of the fluid comprises analyzing the sensed acoustic signal at each of the predetermined modulation frequencies.

6. The method ofclaim 1 wherein exposing the sample to a light of a predetermined wavelength at a predetermined modulation frequency comprises exposing the sample to a plurality of narrow band light beams wherein each light beam is at a different predetermined wavelength.

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