Fluid Phase Measurement using Optical, Microfluidic and Nanofluidic Methods
by
Bo Bao
A thesis submitted in conformity with the requirements for the degree of Doctor of Philosophy Mechanical & Industrial Engineering University of Toronto
© Copyright by Bo Bao 2016
Fluid Phase Measurement using Optical, Microfluidic and Nanofluidic Methods
Bo Bao
Doctor of Philosophy
Mechanical & Industrial Engineering University of Toronto
2016
Abstract
Understanding fluid phase behavior is essential to a wide range of applications, including oil and
gas recovery, chemical reactor engineering, transport and storage of natural gas and carbon
dioxide, and supercritical fluid processing and extraction. In this thesis, novel experimental
methods – optical, microfluidic and nanofluidic - are developed to measure and understand fluid
phase behaviors for carbon dioxide transport/storage and shale gas/oil production. (i) Optical
thin-film interference based bubble and dew point sensor probe: The sensor probe within a small
pressure-volume-temperature (PVT) system offers accurate (< 5% error) and responsive
measurement (1-to-2 orders faster than the conventional method) of bubble and dew point of
both pure fluids and mixtures up to 80 oC and 10 MPa. This approach also allows in situ
measurement of the thickness of condensed liquid film to 1 µm accuracy. (ii) Refractive index based optical fiber sensor: This approach takes advantage of the sharp refractive index difference
between different phases. The optical fiber successfully distinguishes supercritical CO2 and brine at sequestration pressure and temperature conditions. In addition, the CO2-saturated brine is
detectable relative to unsaturated brine – a minute refractive index difference. (iii) Multiplexed
microfluidic-based phase diagram mapping: Demonstrated here is the direct measurement of the ii full Pressure-Temperature phase diagram with 10,000 microwells. The method is tested with a pure fluid and a fluid mixture. Liquid, vapor and supercritical regions are clearly differentiated, and the critical point is measured within 1.2% error on a single chip. This method provides 100- fold improvement in measurement speed over conventional methods. (iv) Nanofluidics-based measurement of bubble nucleation and growth in nanochannels: A nanofluidic platform is developed to investigate vapor bubble nucleation and growth in a pure hydrocarbon confined in sub-100-nm channels. Measured nucleation conditions in the nanochannels are compared with those predicted from the nucleation theory. In addition, different types of bubble growth dynamics are observed and analyzed. Collectively these contributions leverage optics and microfluidics to develop fast and accurate fluid phase measurement methods, and leverage nanofluidics to study the unique effects of nanoconfinement on fluid phase behavior.
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Acknowledgments
It is a great joy for me to express my appreciation to all of you who have supported me academically or spiritually during my PhD journey.
Foremost, I would like to express my deep and sincere gratitude to my academic supervisor Professor David Sinton for his incalculable guidance and support to my PhD study and research. It is his intelligence, enthusiasm, patience, encouragement and profound knowledge that helped me achieving the honorable degree. Thank you to my supervisor.
Also, I would like to thank all my thesis committee: Professor Anthony Sinclair, Professor Markus Bussmann and Professor Nikos Varotsis, for their insightful comments and suggestions to my PhD thesis. And, I would like to thank Professor Peter Wild from University of Victoria for his co-supervision on the work in Chapter 4 and Dr. Farshid Mostowfi from Schlumberger Doll-Research Center (moved from Schlumberger DBR Edmonton) for the collaboration on the work in Chapter 6.
Moreover, I would express my thanks to all my colleagues for their help to my PhD work. Specially, thanks to Dr. Hossein Fadaei for his expertise in petroleum and his help to my research in first two years. My sincere thanks also go to Dr. Jason Riordon, Dr. Huawei Li and Dr. Hadi Zandavi who worked closely with me and supported my research work in last two years. In addition, thanks to three summer students who assisted my work, Haiyi Wang, Japinder Nijjer and Yi Xu.
Finally and importantly, I would like to express my deep appreciation to my parents, Pingyuan Bao and Junqing Shi, for their endless and invaluable support throughout my PhD journey and my life. I could not make the achievement without them. Thank you to my parents.
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Table of Contents
Contents
Acknowledgments...... iv
Table of Contents ...... v
List of Tables ...... viii
List of Figures ...... ix
List of Appendices ...... xviii
1 Thesis Overview ...... 1
1.1 Research motivation ...... 1
1.1.1 Carbon transport and sequestration ...... 1
1.1.2 Shale gas/oil production ...... 4
1.2 Thesis structure ...... 6
2 Introduction ...... 8
2.1 Fluid phases ...... 8
2.2 Experimental methods to measure fluid phase ...... 12
2.2.1 PVT experiments ...... 14
2.2.2 Optical methods ...... 17
2.2.3 Electrical and acoustic methods ...... 19
2.2.4 Microfluidic methods ...... 20
2.2.5 Nanofluidic methods ...... 23
3 Detection of Bubble and Dew Point using Optical Thin-film interference ...... 29
3.1 Introduction ...... 29
3.2 Experimental ...... 31
3.2.1 Experimental setup...... 31
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3.2.2 Sensing mechanism: thin-film interference ...... 32
3.2.3 Experimental procedure ...... 35
3.3 Results and discussion ...... 35
3.3.1 Method validation with pure CO2 ...... 35
3.3.2 Application to industrial CO2 mixtures containing impurities ...... 40
3.3.3 Comparison with existing methods of gas mixture properties ...... 43
3.3.4 Film thickness determination ...... 45
3.3.5 Resolution ...... 45
3.3.6 Repeatability ...... 46
3.4 Conclusion ...... 46
3.5 Supplemental material ...... 47
4 Detecting Supercritical CO2 in Brine at Sequestration Pressure with an Optical Fiber Sensor ...... 50
4.1 Introduction ...... 50
4.2 Experimental ...... 52
4.2.1 Optical fiber sensor ...... 52
4.2.2 High-pressure apparatus...... 54
4.2.3 Characterization of the optical fiber sensor ...... 56
4.2.4 Detection of scCO2 relative to brine ...... 56
4.2.5 Detection of CO2-saturated brine relative to brine ...... 57
4.3 Results and discussion ...... 58
4.3.1 Characterization of the optical fiber sensor ...... 58
4.3.2 Detection of scCO2 relative to brine ...... 59
4.3.3 Detection of CO2-saturated brine relative to brine ...... 62
4.4 Implications...... 65
4.5 Supplemental material ...... 65
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5 Direct Measurement of the Fluid Phase Diagram using Multiplexed Microfluidics ...... 67
5.1 Introduction ...... 67
5.2 Measurement of pressure-temperature phase diagram of pure CO2 ...... 69
5.3 Measurement of pressure-temperature phase diagram of 95% CO2 + 5% N2 mixture ...... 73
5.4 Phase-mapping device accuracy and speed ...... 74
5.5 Conclusion ...... 75
5.6 Supporting information ...... 75
6 Bubble Nucleation and Growth in Nanochannels ...... 78
6.1 Introduction ...... 78
6.2 Experimental setup...... 80
6.3 Results and discussion ...... 81
6.3.1 Bubble nucleation ...... 81
6.3.2 Bubble growth ...... 84
6.4 Conclusion ...... 90
6.5 Supplemental material ...... 91
7 Conclusions ...... 98
7.1 Fluid phase measurement using optical methods...... 98
7.2 Fluid phase diagram mapping using multiplexed microfluidics ...... 99
7.3 Fluid phase change in nanochannels ...... 99
7.4 Outlook ...... 100
References ...... 101
Appendix 1 ...... 110
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List of Tables
Table 3-1. Dew points and bubble points of pure CO2 ...... 48
Table 3-2. Dew points and bubble points of impure CO2 ...... 49
Table 6-1. Bubble nucleation conditions ...... 91
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List of Figures
Figure 1-1. Sources (where CO2 is captured) and sinks (where CO2 is stored) of global CCS projects. Reproduced with permission from International Energy Agency,[4] copyright 2013.1 .. 2
Figure 1-2. Assessed world shale gas and oil resources. Reproduced with permission from U.S. Energy Information Administration,[12] copyright 2013...... 4
Figure 1-3. SEM image of Fayetteville shale. A) micro-porosity (scale bar = 5 µm); B) organic matter and nano-porosity (scale bar = 500 nm); C) nano natural factures (scale bar = 1 µm); D) pore size histogram; E) Hydraulic fracturing. Reproduced with permission from Elsevier, [16] copyright 2013...... 5
Figure 2-1. Molecule arrangement in solid, liquid, and gas phases. Reproduced with permission from McGraw Hill [24], copyright 2012...... 8
Figure 2-2. Phase diagrams of pure substance. a) Temperature-Volume (T-v) diagram, b) Pressure-Volume (P-v) diagram, and c) Pressure-Temperature (P-T) diagram. Reproduced with permission from McGraw Hill,[24] copyright 2012...... 9
Figure 2-3. Pressure-Temperature phase diagram of A) water, and B) carbon dioxide; C) Images o of CO2 phases at different Pressures and Temperatures. The critical point of CO2 is 31.0 C and 7.38 MPa. Reproduced with permission from Elsevier,[25] copyright 2014...... 11
Figure 2-4. P-T phase envelope of natural gas. The circle stands for critical point. Composition of natural gas mixture is listed at right. Reproduced with permission from Taylor & Francis Group,[9] copyright 2015...... 12
Figure 2-5. A) PVT Analytical-isothermal methods for phase measurement; B) Synthetic method (visual and non-visual). Reproduced with permission from Annual Review of Chemical and Biomolecular engineering,[10] copyright 2013...... 13
Figure 2-6. Typical PVT experiments of a reservoir fluid. A) Pressure, volume and temperature conditions of PVT cells used for different reservoir fluids; Schematics of constant-mass expansion experiment for B) an oil mixture and C) a gas condensate; D) Schematics of
ix differential depletion experiment for oil; E) Schematics of constant-volume depletion experiment for a gas condensate. Reproduced with permission from Taylor & Francis Group,[9] copyright 2015...... 15
Figure 2-7. Optical methods: A) Schematics of automatic chilled mirror method;[28] B) Principle of Tunable Diode Laser Absorption Spectroscopy (TDLAS);[29] C) Schematics of Fabry-Perot hygrometer; [28] D) Schematics of fiber-optic reflectometer;[30] Reproduced with permission from GE Measurement & Control, Ametek Process Instruments, and, AIP Publishing LLC, copyright 2006...... 17
Figure 2-8. Electrical methods: A) Capacitance probe and operating principle; B) Quartz-crystal microbalance (QCM) sensors and operating principle.[29] Reproduced with permission from Ametek Process Instruments, copyright 2011...... 19
Figure 2-9. A microfluidic PVT system. A) Concept of bubble point measurement: bubble forms below bubble point pressure at the inlet restriction. B) Image sequence of bubble evolution at the inlet restriction (5000 fps). C) Image of the microfluidic PVT system in operation, showing bubble and liquid slugs. Reproduced with permission from Royal Society of Chemistry,[11] copyright 2012...... 21
Figure 2-10. A microfluidic system investigating thermodynamics at high pressures and temperatures. A) Schematics of the microfluidic system with the key features of the serpentine channel. B) Analogy of two operation modes: “continuous flow” and “dynamic stopflow mode”. C) Measurement of phase envelop with detected bubble point and dew point. Reproduced with permission from Royal Society of Chemistry,[35] copyright 2014...... 22
Figure 2-11. Two microfluidic systems measuring the phase behavior of multicomponent
samples. A) Detection of water dew point in CO2 stream. B) Measurement of the minimum
miscibility pressure of CO2 in crude oils. Reproduced from American Chemical Society, [36][37] copyright 2014 and 2015...... 23
Figure 2-12. Study of bubble nucleation by a local heating source. A) Schematics of experimental setup for boiling on surfaces with fabricated cavities and posts; B) Enlarged images of cavities and posts; C) Experimental data of water boiling temperature in experimental
x conditions and theory predictions. Reproduced with permission from American Institute of Physics, [38] copyright 2012...... 25
Figure 2-13. A) Nanochannel device including sets of nanochannels; B) Cavitation induced by deformed meniscus and bubble entrapment at the nanochannel entrance; C) Image sequence of cavitation in 58-nm nanochannels. Reproduced with permission from Proceedings of the National Academy of Sciences of the United States of America,[23] copyright 2012...... 26
Figure 2-14. Cavitation test of water in nano-porous media. A) Top view and B) Side view schematics of ink-bottle structure filled with water; Porous silicon (poSi) is interconnected to these cavities; C) Optical images show evaporation occurred from edges of sample. Reproduced with permission from American Physical Society, [39] copyright 2014...... 27
Figure 2-15. Study of nanoconfinement effect in hydrocarbon production. A) Structure of nanofluidic chip; B) SEM image of nanochannels; C) Experiment of water displacing nitrogen gas; D) Pentane evaporation in nanochannels; E) Evaporation of a ternary mixture stopped in one of the microchannels. Reproduced with permission from Society of Petroleum Engineers,[20][26] copyright 2014...... 28
Figure 3-1. a) Schematic of experimental apparatus integrating gas cylinder, pump, PVT cell, optical interrogator, and computer; b) Internal features of the PVT cell with optical fiber sensors...... 32
Figure 3-2. a) Schematic of single phase fluid surrounding the fiber tip; b) , i.e. Schematic of a liquid film on fiber tip while surrounding medium is vapor phase, i.e., Phase I = liquid, Phase II = vapor. Thin-film interference is an additive effect of a wave reflected at the Core/Phase I interface (dotted curve) and a wave reflected at the Phase I/Phase II (dashed curve). No phase shift results in a constructive wave returning to the detector, where as a 180° wave phase difference returns a destructive wave. Thus, the presence of thin film – indicating vapor-liquid phase transition - can be very accurately determined by the optical fiber sensor via constructive and destructive wave patterns in the reflection spectrum. It is also possible to extract further measurements from this returning signal, such as film thickness...... 33
o Figure 3-3. Detection of bubble and dew point of pure CO2 at 20 C. a) Reflection spectrum of top sensor under decreasing pressure: The interference pattern observed at 54 bar indicates the xi formation of a thin film corresponding to the bubble point; b) Corresponding average power vs. pressure: A large interference fluctuation band at 54 bar (3.57 dBm) indicates the phase transition; c) Reflection spectrum of the bottom sensor under increasing pressure: The interference pattern observed at 55 bar indicates the dew point; d) Corresponding average power vs. pressure: A large interference fluctuation at 55 bar (3.24 dBm) indicates the phase transition. (Note: error bars are included in plots (b) and (d), however they are smaller than the data-point markers; pressure lines in (a) and (c) appear overlapped in single phase and shift significantly during phase transition.)...... 36
Figure 3-4. Detection of critical point of CO2 – lowest temperature at which no interference pattern is observed a) Reflection spectrum from the top sensor under decreasing pressure; b) Corresponding average power vs. pressure; c) Reflection spectrum from the bottom sensor under increasing pressure; d) Corresponding average power vs. pressure. No interference observed in a) or c) indicates the absence of two phase region, and, smooth variation of average power with constant noise-level standard deviations (0.12 - 0.17 dBm) showed in b) and d) implies a smooth phase change characteristic of supercritical behavior. (Note: error bars are included in plots (b) and (d), however they are smaller than the data-point markers) ...... 39
o Figure 3-5. Detection of bubble and dew point of impure CO2 at 20 C. a) Reflection spectrum of top sensor under decreasing pressure: The interference pattern observed at 87 bar indicates the formation of a thin film corresponding to the bubble point; b) Corresponding average power vs. pressure: A large interference fluctuation band at 87 bar (0.84 dBm) indicates the phase transition; c) Reflection spectrum of the bottom sensor under increasing pressure: The interference pattern observed at 67 bar indicates the dew point; d) Corresponding average power vs. pressure: A large interference fluctuation at 67 bar (0.62 dBm) indicates the phase transition. (Note: Pressure lines in (a) and (c) appear overlapped in single phase and shift significantly during phase transition.)...... 41
Figure 3-6. Detection of maxcondentherm point of impure CO2. a) Reflection spectrum from the top sensor under decreasing pressure; b) Corresponding average power vs. pressure; c) Reflection spectrum from the bottom sensor under increasing pressure; d) Corresponding average power vs. pressure. No interference was observed in a) or c), and a smooth variation of
xii the average power with constant deviation (0.12 – 0.19) implies a continuous phase change. The maxcondentherm point was identified at 26 oC and 82 bar...... 42
Figure 3-7. Comparison of bubble and dew points measured and predicted by two models
(REFPROP and PVTsim) for both the case of pure CO2 and impure CO2. The pure CO2 case provides method validation. The dew point data in the impure case shows a good agreement with the models. Both the models and the experimental data deviate substantially for the bubble point of the case with impurities, highlighting the importance of composition-specific testing enabled by the small scale PVT method...... 43
Figure 3-8. Example of bubble point detection with increased resolution using reduced pressure intervals of 0.1 bar. a) Reflection spectrum from the top sensor under decreasing pressure from 88 to 87 bar: The interference pattern observed at 87.4 bar indicates the formation of a thin film corresponding to the bubble point; b) Corresponding average power vs. pressure: A large interference fluctuation band at 87.4 bar indicates the phase transition, with resolution of 0.1 bar...... 45
Figure 3-9. Repeatability test of sensor for bubble and dew point measurement of impure CO2 at 20 oC...... 46
Figure 4-1. Schematic of the CO2 sensing method developed here. As light traveling through the fiber encounters the long-period grating, specific resonant wavelengths are scattered outwards into the surrounding medium. The resulting transmission spectrum displays an attenuation band.
A contrast between the native brine solution and either scCO2 or CO2-saturated brine is detected through a resonance wavelength shift...... 53
Figure 4-2. Schematic of the high-pressure apparatus used to characterize and test the optical
fiber sensor. (a) The setup employed for detecting scCO2 relative to brine solution, and (b) the
contents of the cylinders used for detecting CO2-saturated brine relative to brine. The pressure of 1400 psi (9.65 MPa) was monitored by pressure gauges (G1 to G3) while the temperature of 40 °C was controlled by the water bath...... 54
Figure 4-3. a) The transmission spectrum of the optical fiber sensor corresponding to DI water and air at 40 °C. The resonance wavelengths are found to be 1556.102 nm in DI water and 1557.705 nm in air. Given the refractive index value of air (1.0002 RIU) and DI water (1.3309 xiii
RIU) at 40 °C, the sensitivity to refractive index (between 1.00 and 1.33) is determined to be 4.847 nm / RIU. b) The resonance wavelength shift as a function of pressure and temperature. The resonance wavelength shift shows linear correlations with both pressure and temperature, with the correlation coefficients (R2) of 0.9881 and 0.9959, respectively. The sensitivities to pressure and temperature are 0.026 nm / 100 psi (0.69 MPa) (1000 - 1800 psi, or 6.89 to 12.41 MPa) and 0.054 nm / °C (35 – 45 °C), respectively...... 58
Figure 4-4. The resonance wavelength shift corresponds to the alternate cycles of test samples
between brine (red rectangles) and scCO2 (green diamonds). Each cycle includes a 10-min time gap for sample replacement and stabilization plus a 5-min period for data collection. A moving average curve is shown as a solid line, and a dashed trend line between data collections is shown as a guide for the eye. The brine and scCO2 are distinguished repeatedly and significantly in terms of the resonance wavelength shift, 1.149 nm as the average value...... 60
Figure 4-5. The resonance wavelength shift corresponding to CO2-saturated brine solution (blue circles) as compared to the original brine solution (red rectangles). Data are collected in 5-min periods at 15-min intervals. A moving average is plotted as a solid line, and a dashed line provides a guide for the eye between data sets. The saturation equilibrium was achieved after 100
minutes from t = 5 min when scCO2-brine solution replaced the initial brine. A detectable
resonance wavelength shift of 0.192 nm is observed for CO2-saturated brine relative to the original brine solution...... 62
Figure 4-6. a) A high-pressure stainless steel chamber (cross-section view) to enclose and immobilize the optical fiber sensor. The chamber is assembled from 1 threaded pipe nipple, 2 threaded pipe fitting Tees and 4 Yor-lok tube fitting adapters as four ports (namely Port A, B, C and D). The optical fiber sensor is tensioned and suspended through the chamber cavity via Port A and B, and, the long period grating section is adjusted to locate at the center of the pipe nipple. b) A tight sealing between the fitting and the optical fiber. The optical fiber passes through a PEEK sleeve and the PEEK sleeve passes through a compression fitting ferrule. The fitting ferrule compresses on the PEEK sleeve when the nut thread is tightened so that the PEEK sleeve shrinks and tightly clamps on the optical fiber...... 66
Figure 5-1. a) Schematic of the microfluidic fluid phase-mapping device. a) Full device featuring a 2D array of micro-wells subject to a vertical pressure gradient and a horizontal temperature xiv gradient. Only a few channels are displayed for clarity; the actual phase-mapping device contains 100 horizontal channels, each with 100 micro-wells. b) Enlarged view of micro-wells...... 69
Figure 5-2. Measurement of the pressure-temperature phase diagram of pure CO2. a) Phase- mapping device in operation, with liquid, vapor and supercritical regions visualized. b) Microscope image of a region of the phase-mapping device with the critical point. Inset images show enlarged views of three liquid-vapor interfaces. c) Pixel intensity profile across corresponding liquid-vapor interfaces. Inset shows how the height-to-width ratio of the pulses changes near the critical point. d) Pressure-temperature phase transition point measurements and validation with NIST reference points. Inset images show typical fluid behavior within micro- wells at various pressure-temperature conditions...... 72
Figure 5-3. Measurement of the fluid phase diagram of a 95 % CO2 + 5 % N2 mixture and comparison to NIST reference. Inset images show typical fluid behavior within micro-wells at various P-T conditions...... 74
Figure 5-4. a) Schematic of the experimental setup. Water was flowed between baths and chiller and heater blocks above the phase-mapping device to produce a temperature gradient. Two pumps (Teledyne Isco) were attached to the inlet and outlet to pressurize the system, and drive single-phase flow through the resistor channel. A piston (filled with the fluid of interest) was used to isolate the first pump from the device (which was filled with water). A custom stainless- steel manifold was used to provide a strong connection to the device. A microscope monitored the phase-mapping device during operation. Pressure transducers measured pressures at the inlet and outlet throughout the experiments. b) Image of the phase-mapping device operating with pure CO2...... 75
Figure 5-5. Temperature characterization of the phase-mapping device: a) Image of temperature calibration test using propane. b) Temperature distribution of phase-mapping device during test of pure CO2 and mixture of 95% CO2 + 5% N2...... 76
Figure 5-6. The response of liquid-vapor interface position to inlet pressure changes. Insets show microscope images of interface positions at various pressure states...... 77
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Figure 6-1. a) Schematic of the experimental setup including micro/nanofluidic chip and top view of the chip; b) Side view, and c) Cross-section view of 85-nm deep nanochannels; d) Cross- section view of single nanochannel by SEM imaging...... 81
Figure 6-2. Measurements of bubble nucleation in 85-nm nanochannels. Plotted for comparison are the saturation vapor pressure, capillary pressure calculated from the Kelvin Equation, Eq(6-
1), the prediction from the classical nucleation theory, Eq(6-2) for tN = 900 s, and the spinodal limit from Eq(6-3)...... 82
Figure 6-3. Mechanisms of bubble column growth at Tl = 347 K and Pl = 1.60 MPa: a) Image sequence of Type A growth where vapor bubble nucleates at channel-end; b) Image sequence of
Type B where vapor bubble nucleates along the channel; c) Bubble length lB versus time of Type
A and B growth; d) Positions of left and right liquid-vapor interfaces, lL and lR, bubble length lB of Type B growth. Three distinct growth regimes can be identified: “Transient start-up”, “Transitional” and “Steady linear growth”...... 85
Figure 6-4. a) Vapor bubble column growth lB(t) of Type A at five different temperatures; inset
shows the calculated evaporation rate dNv/dt in steady linear growth regime; b) The calculated
pressure in the vapor phase Pv versus time of the bubble nucleation experiment at T = 347 K. Saturation pressure and the reservoir pressure are also plotted for comparison...... 89
Figure 6-5. Complete data of bubble nucleation time and associated growth types of the ten nanochannels at five nucleation conditions...... 92
Figure 6-6. Complete data of left interface velocity uL in the steady linear growth regime of the ten nanochannels at five nucleation conditions...... 92
Figure 6-7. Complete data of right interface velocity uR of Type B growth in the nanochannels at five nucleation conditions...... 93
Figure 6-8. The relative position of right liquid-vapor interface in the transient start-up regime of the type B growth in the five nucleation conditions. It is clear that the right interface moves linearly with time in the “transient start-up” regime. The inset shows the right interface velocity,
uR, at five nucleation conditions. The uR increases from 0.3868 to 0.8709 µm/ms as the temperature increases from 343 to 362 K...... 93 xvi
Figure 6-9. Mechanisms of bubble column growth at Tl = 343 K and Pl = 1.10 MPa: a) Bubble
length lB versus time of Type A and B growth; b) Positions of left and right liquid-vapor
interfaces, lL and lR, of Type B growth; c) Predicted bubble pressure Pv (Type A) during bubble column growth...... 94
Figure 6-10. Mechanisms of bubble column growth at Tl = 352 K and Pl = 2.00 MPa: a) Bubble
length lB versus time of Type A and B growth; b) Positions of left and right liquid-vapor
interfaces, lL and lR, of Type B growth; c) Predicted bubble pressure Pv (Type A) during bubble column growth...... 95
Figure 6-11. Mechanisms of bubble column growth at Tl = 357 K and Pl = 2.40 MPa: a) Bubble
length lB versus time of Type A and B growth; b) Positions of left and right liquid-vapor
interfaces, lL and lR, of Type B growth; c) Predicted bubble pressure Pv (Type A) during bubble column growth...... 96
Figure 6-12. Mechanisms of bubble column growth at Tl = 362 K and Pl = 2.90 MPa: a) Bubble
length lB versus time of Type A and B growth; b) Positions of left and right liquid-vapor
interfaces, lL and lR, of Type B growth; c) Predicted bubble pressure Pv (Type A) during bubble column growth...... 97
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List of Appendices
Appendix 1: Silicon-glass micro/nanofluidic chip fabrication procedure
xviii 1
1 Thesis Overview
1.1 Research motivation
Fluid phase measurement is crucial in a broad range of processes, including oil and gas recovery, chemical reactor engineering, transport and storage of natural gas and carbon dioxide, and supercritical fluid processing and extraction. The research topics described in Chapter 3 to 6 are motivated by two broad applications outlined below: Carbon transport and sequestration; and shale gas/oil production.
1.1.1 Carbon transport and sequestration
Global CO2 emission increased 0.5 % in 2014 compared to the previous year, reaching 35.5 Gt total emissions.[1] Current emission rates point to a global temperature increase over 5°C by 2100. The global temperature increase would cause serious consequences, including sea level rise, dislocation of human settlement, extreme weathers, reduced food production and human disease. [2] Despite of fast development of sustainable energy, it is clear that the fossil fuel dominant energy portfolio cannot be significantly changed in a short term, particularly considering the fact that fossil fuels contribute to 86.3 % of global energy in 2014 (23.7% Natural gas, 30% Coal and 32.6% Oil).[1] The International Energy Agency indicates that Carbon Capture and Storage (CCS) is a critical component in the portfolio of low-carbon
solutions. CO2 could be captured from large point sources, including gas processing plants, gas or coal power plants, fertilizer plants, ethanol plants and other large industrial emitters (Figure 1-
1). The captured CO2 could be further used for enhanced oil recovery, or stored in depleted oil/gas field and deep saline aquifers (Figure 1-1). Figure 1-1 B assesses 29 global CCS projects, including 16 in North America, 10 in Europe and 3 in rest of the world. Though deep saline aquifers shows tremendous potential for direct storage (100 – 10,000 Gt estimated [3]), the only currently economic carbon sink option is combined storage and enhanced oil recovery by injecting CO2 into oil fields.
2
Figure 1-1. Sources (where CO2 is captured) and sinks (where CO2 is stored) of global CCS projects. Reproduced with permission from International Energy Agency,[4] copyright 2013.1
CO2 pipelines connect the sources and sinks. To ensure safe and corrosion-free operation, there
are strict specifications for CO2 in terms of delivery composition, pressure and water content.
First, 95% purity of CO2 is usually required considering common impurities of H2O, N2, O2, H2S and CO in the stream. Second, water content is required to be less than 640 ppmv to avoid corrosion – notably any liquid water separated from the mixture quickly becomes acidic due to
the CO2.[4] It is also desirable to have the entire pipeline run as a single supercritical phase because multiple phases cannot be tolerated by pumps and compressors. The presence of
impurities significantly changes the phase behavior of CO2 stream. Therefore, it is critical to
3
develop and utilize appropriate technology to characterize the phase behavior of industrially-
relevant CO2 streams. This motivates the research topic of developing novel technique to detect
phase boundary for CO2 pipeline mixtures, as described in Chapter 3.
Environmental and health risks are major concerns surrounding carbon sequestration technology. It is crucial to ensure the process of injection and sequestration are safe without any leakage.
Developing technologies to detect and monitor CO2 plumes underground is necessary to ensure
safety. A wide variety of subsurface CO2 monitoring methods have been investigated, including seismic[5], geoelectric [6] and geochemical methods[7]. Optical methods are relatively new and are becoming more and more popular in subsurface tools, due to their inherent advantages including in-situ measurement, immunity to electromagnetic noise, high sensitivity and capacity for distributed sensing. The most successful deployment of optical fiber sensors underground is distributed temperature sensing (DTS) [8]. This recent work motivates the development of an
optical fiber sensor to distinguish CO2 phase from the formation water phase, as described in Chapter 4.
A major limitation of all available phase measurement technologies is that only a single pressure- temperature condition can be measured at once. The most common configuration is the pressure- volume-temperature (PVT) cell, ubiquitous in petrochemical and polymer processing applications.[9][10] These cells typically vary in size between 100 mL and 1 L, and reach pressures and temperatures up to 60 MPa and 150 °C, respectively.[9] Since thermal and chemical equilibrium within these large systems must be reached between measurements, obtaining a single P-T data point typically takes 8 to 10 h [11]. Thus tens to hundreds of hours are required to generate a full phase diagram at a considerable expense. Microfluidic techniques provide a unique solution to integrate a large number of data points in a relatively small space with accurate control of temperature and pressure. Developed here is a novel PVT system which can generate a P-T diagram in a single run with 10,000 parallel microwells, as described in Chapter 5.
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1.1.2 Shale gas/oil production
Figure 1-2. Assessed world shale gas and oil resources. Reproduced with permission from U.S. Energy Information Administration,[12] copyright 2013.
The single most significant change in the global energy system in the last 10 years has been the emergence of shale gas and tight oil, achieved via hydraulic fracturing in horizontal wells. The result has been a flood of hydrocarbons, a rapid drop in oil and gas prices with associated global economic impacts, and the re-emergence of US production long thought to have peaked (peak oil theory). The implications for Canada are profound. Global technically recoverable resources of shale gas and shale/tight oil reached 7,299 trillion cubic feet and 345 billion barrels in 2013 indicated by a report from U.S. Energy Information Administration. The vast resources of hydrocarbons in these shale/tight formations contribute to 10% increase of crude oil and 48% increase of natural gas due to inclusion of shale oil and shale gas. [12] Figure 1-2 shows the global geological distribution of shale gas and oil formation. In contrast to conventional reservoirs, shale/tight formation pores are much smaller, with typical size of tens to hundreds of nanometers. Due to the nano-porosity, the production of these hydrocarbons out of nanopores requires hydraulic fracturing. During hydraulic fracturing, fracking fluid (water + trace amount of proppants) is injected into a wellbore to create artificial cracks in the formations. Once
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the hydraulic pressure is removed from the well, the proppants hold the fractures open. Such fractures expose and connect large areas of hydrocarbon-bearing nanopores and hydrocarbon is released to production wells. This is a complex process involving coupled fluid mechanics and nanoscale fluid phase behavior which is poorly understood, a “blank page with huge impact” as described in a recent review[13]. The immediate need for fundamental and applied research in this area is underscored by both a 2014 special issue of Science [14], and a 2014 report by the Council of Canadian Academies[15].
Figure 1-3 A-C) shows typical structure of shale with nanopores by SEM. The pore size distribution of the imaged shale range from 30 to 60 nm, as presented by the histogram in Figure 1-3 D. Hydraulic fracturing process is illustrated in Figure 1-3 E.
Figure 1-3. SEM image of Fayetteville shale. A) micro-porosity (scale bar = 5 µm); B) organic matter and nano-porosity (scale bar = 500 nm); C) nano natural factures (scale bar = 1 µm); D) pore size histogram; E) Hydraulic fracturing. Reproduced with permission from Elsevier, [16] copyright 2013.
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Phase behavior of hydrocarbons in nanopores is a key element in understanding this complex physical process. A better understanding of this physics is crucial to both maximizing the energy efficiency of these operations, and quantifying their environmental impact. Previous work on phase behavior in nanoconfinement is mostly numerical and analytical [17][18][19]. However, there are very few experimental studies to validate these results. Nanofluidic methods – developed primarily for biomolecular separations and biomedical applications – can provide a window into fluid phase behavior at the nanoscale. Some in the oil and gas research community have developed nanofluidic systems to study hydrocarbon transport [20][21]. These recent studies show a rich physics, with deviation from classical theory in terms of capillary pressure and interface shape [22][21]. There are relatively few studies, however, a recent article in PNAS shows highly anomalous behavior on water evaporating from a nanochannel in a water-air system [23]. The lack of experimental investigation in nanofluidic motivates the research topic of hydrocarbon liquid-vapor phase change, as detailed in Chapter 6.
It is worthy to mention that, the developed sensors and systems from Chapter 3 to 6 are not limited to the specific motivations, but can be used in a much wider range of applications. Specifically, (i) the optical bubble and dew point sensor (Chapter 3) can be used to characterize the phase envelop of any fluid mixture (pressure-, temperature- and chemical-tolerant) or to measure the thickness of thin film deposition on the order of 1 µm; (ii) the optical fiber sensor (Chapter 4) can be used to distinguish any two phases with a difference of refractive indices down to ~ 0.04 R.I.; (iii) the phase mapping device (Chapter 5) can be utilized in phase diagram mapping of a variety of pure fluids or the measurement of critical points in fluid mixtures within the broad temperature and pressure range of the device; and (iv) the nanofluidic platform (Chapter 6) could be applied to study phase behavior in nanoconfinement of other fluids, e.g. water, organic solvents, refrigerant and other hydrocarbons such as reservoir relevant tight-oil mixtures or fracture fluids.
1.2 Thesis structure
The thesis describes the author’s contributions in fluid phase measurement by using novel optical, microfluidic and nanofluidic approaches for the applications of carbon transport and sequestration, and, shale oil/gas production. These contributions leverage optics and
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microfluidics to develop fast and accurate fluid phase measurement methods, and leverage nanofluidics to study the unique effects of nanoconfinement on fluid phase behavior.
Chapter 1 briefly describes the research motivations from two industrial processes: Carbon Transport and Sequestration; and shale gas/oil production. This chapter discusses the key aspects of these two industrial processes most closely associated with this work and briefly describes the demand for novel phase measurements in that context.
Chapter 2 begins with the key concepts used in this thesis. These concepts include phase, fluid phase diagram, and typical phase behavior of pure substance and mixtures. Then the latter section of this chapter presents a short literature review of existing techniques for fluid phase measurement, including typical pressure-volume-temperature (PVT), electrical, optical, microfluidic and emerging nanofluidic approaches.
Chapter 3 presents the thin-film interference based optical approach to detect bubble and dew point of CO2 and industrial CO2 mixtures. This chapter was published in Sensors and Actuators B: Chemical.
Chapter 4 presents the refractive-index sensing based optical approach to distinguish CO2 phase from brine phase. This chapter was published in Environmental Science and Technology.
Chapter 5 describes the microfluidic approach rapid mapping of pressure-temperature phase diagram of CO2 and a CO2-N2 mixture. This chapter manuscript has been submitted to Journal of the American Chemical Society (Communications).
Chapter 6 presents a nanofluidic platform to study cavitation and bubble growth of pure hydrocarbon (propane). This chapter manuscript has been submitted to Physical Review Letters.
Chapter 7 summarizes the author’s contribution in optical, microfluidic and nanofludic methods measuring fluid phase. This chapter also includes an outlook for the trend of fluid phase measurement technology in the future.
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2 Introduction
2.1 Fluid phases
Figure 2-1. Molecule arrangement in solid, liquid, and gas phases. Reproduced with permission from McGraw Hill [24], copyright 2012.
Substances exist in solid, liquid and gas phases. In the solid phase, molecules are at relatively fixed positions with three-dimensional repeatable patterns. The distance between molecules is relatively small which keeps molecules attracted to each other. When the temperature is increased, the velocity of molecules reaches a threshold point where the attractive forces are overcome and the “pattern” breaks away, which is known as the melting process from solid to liquid. The molecules in the liquid phase have weaker inter-molecular forces and the “freedom” of the molecular movement is higher than it is for a solid. Once temperature is increased or pressure is decreased, the molecule structure could not be maintained at a relatively fixed position, instead the molecules start moving randomly which forms gas phase where molecules are spaced in relatively large distance. The molecular arrangement in these three phases is illustrated in Figure 2-1.[24] The phase transition from liquid to gas happens in one of two ways: (1) evaporation: where liquid molecules escape from the liquid-vapor interface and forms a gas phase; (2) boiling: where gas bubbles nucleate and grow inside the entire mass of liquid. Conversely, phase transition from gas to liquid is defined as condensation, where gas molecules form a liquid molecular pattern.
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Figure 2-2. Phase diagrams of pure substance. a) Temperature-Volume (T-v) diagram, b) Pressure-Volume (P-v) diagram, and c) Pressure-Temperature (P-T) diagram. Reproduced with permission from McGraw Hill,[24] copyright 2012.
Three basic thermodynamic properties of fluid, i.e. temperature, pressure and volume, are usually studied and expressed by property diagrams. Typical property diagrams are T-v, P-v and P-T diagrams.
Figure 2-2 a) shows a typical T-v diagram of a pure substance. At constant pressure P1, a heated pure substance undergoes compressed liquid, saturated liquid-vapor coexistence and superheated vapor (dash line). Saturation temperature is defined as the temperature at which a substance changes phase at a given pressure. Similarly, saturation pressure is defined as the pressure at which a substance changes phase at a given temperature. The horizontal region, “saturate liquid- vapor”, indicates liquid-vapor coexistence in equilibrium. If pressure is increased, this saturation line becomes shorter. If pressure is kept increasing, this saturation line finally shrinks into a point, defined as “critical point”, where the saturated vapor and saturated liquid phases are identical. In other words, there is no explicit boundary between liquid and vapor phases.[24] Similarly, Figure
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2-2 b) is a representative P-v diagram of a pure substance. Instead of P = constant in T-v diagram, temperature T is kept constant and phase change curve goes a downward trend in the direction of increasing v.
Figure 2-2 c) shows the P-T diagram of a pure substance. P-T diagram is usually called phase diagram because all the solid, liquid and vapor phases are distinguished from each other by three lines, i.e., sublimation line, melting line and vaporization line. All the three lines meet at triple point where three phases coexist in equilibrium. Critical point is the end point of the vaporization line when there is no phase boundary between liquid and vapor phases.[24] It is noteworthy that the focus of this thesis is the “fluid” phase transition, or, the “vaporization line”.
Typical phase diagrams of pure fluid are shown in Figure 2-3 A) water and B) carbon dioxide. It is noteworthy that the vaporization line in Figure 2-2 c is generally called the saturation line here in Figure 2-3. The critical point of water is at a temperature of 373.95°C and a pressure of 22.06
MPa. The critical point of CO2 is at a temperature of 31.0°C and a pressure of 7.38 MPa. Since
CO2 is intensively studied in Chapter 3, 4 and 5, visualization images of CO2 phases at different pressures and temperatures are presented in Figure 2-3 C). A clear interface between liquid and vapor phases is observed on the saturation line below the critical point (Figure 2-3 C-a and C-b). Moving along the saturation line towards the critical point, the liquid-vapor interface becomes vaguer and finally vanishes when reaching critical point, as shown from c to g in Figure 2-3 C.
Above the critical point (T > Tcr and P > Pcr), the fluid turns into a “supercritical” phase (h in Figure 2-3 C). The supercritical phase is a uniform phase with gas-like viscosity and liquid-like
density. Generally, liquid phase refers to the region where T < Tcr and P > Psat, while vapor phase refers to the region where T > Tsat and P < Pcr. However, it is also common to distinguish
“compressed fluid” from the liquid phase where T < Tcr and P > Pcr (Figure 2-3 B, and, k in Figure 2-3 C). Similarly, “superheated vapor” can be distinguished from the vapor phase when T >
Tcr and P < Pcr. All phases of vapor, liquid, supercritical, compressed liquid and superheated vapor are labelled in Figure 2-3 B. Typically, there is no sharp boundary between the supercritical phase and the compressed fluid phase (See isobaric transition h-l-k in Figure 2-3 C), and, neither between the supercritical phase and superheated vapor phase (See isothermal transition h-i-j in Figure 2-3 C). [25]
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Figure 2-3. Pressure-Temperature phase diagram of A) water, and B) carbon dioxide; C)
Images of CO2 phases at different Pressures and Temperatures. The critical point of CO2 is 31.0oC and 7.38 MPa. Reproduced with permission from Elsevier,[25] copyright 2014.
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Figure 2-4. P-T phase envelope of natural gas. The circle stands for critical point. Composition of natural gas mixture is listed at right. Reproduced with permission from Taylor & Francis Group,[9] copyright 2015.
The phase diagram of multicomponent systems or fluid mixtures is more complex than that of a pure fluid. Instead of a simple liquid-vapor saturation line in the pure fluid case, a fluid mixture has a two-phase envelope inside which liquid and vapor coexist with different liquid-to-vapor ratios. Figure 2-4 shows the phase envelope of natural gas, a fluid mixture consisting of 90.4%
methane, 5.4% ethane, 2.1% propane, trace amount of CO2 and N2, and other heavier hydrocarbons.[9] The phase envelope boundary is composed of two saturation lines, i.e. a bubble point line and a dew point line. The bubble point is defined as the point where the first bubble is formed out of the liquid phase. Similarly, dew point is defined as the point where the first dew is formed out of vapor phase. The bubble point line and dew point line are joined at the critical point where there is no sharp boundary between the liquid and vapor phases. Other important
points on phase envelope are “cricondenbar” or “maxcondenbar” (P = Pmax), and,
“cricondentherm” or “maxcondentherm” (T = Tmax). It is noteworthy that the maxcondenbar point, maxcondentherm point and critical point are not overlapping for the case of a fluid mixture, as shown in Figure 2-4.
2.2 Experimental methods to measure fluid phase
Understanding the phase behavior of a fluid is particularly important in petroleum reservoir engineering, chemical reactor engineering, the transport and storage of natural gas and carbon dioxide, and, supercritical fluid applications. Fluid phase behavior can be obtained by either
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theoretical/simulation approaches or experimental methods. Theoretical/simulation approaches calculate the thermodynamic properties (P,V, T) for mixtures using the cubic Equation of State (EOS), such as Redlich-Kwong (1949), Soave-Redlich-Kwong (1972), and Peng-Robinson (1978) equations.[9] The majority of phase simulation software applies these EOS or modified EOS to predict the phase behavior of fluid mixtures in different scenarios. For example, the Peng-Robinson EOS [26] and modified van der Walls EOS [17] are applied to study the influence of nano-confinement on phase behavior. Molecular simulations of hydrocarbons in nano-confinement have been motivated by the boom of shale oil/gas.[18][27] By using molecular simulations, inter-molecular forces and wall-molecular force can be predicted. The second approach to obtaining phase behavior is through experimental methods. Since the scope of this thesis is within experimental methods, the remainder of this section focuses on existing experimental methods to measure fluid phase.
Figure 2-5. A) PVT Analytical-isothermal methods for phase measurement; B) Synthetic method (visual and non-visual). Reproduced with permission from Annual Review of Chemical and Biomolecular engineering,[10] copyright 2013.
The existing experimental methods can be categorized into two classes based on whether the compositions of the equilibrium phases are determined in the test (“Analytical”) or the mixture has been prepared with known composition (“Synthetic”).[10] Figure 2-5 A shows analytical- isothermal schematics including charging, mixing & equilibrium, and sampling & analysis. Fluid phase composition is determined by different analytical techniques, e.g. liquid chromatography, gas chromatography and in-situ spectroscopy. The analytical approach is well suited to
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investigating strongly composition-dependent phase boundaries and the main error sources come from the precise determination of chemical composition under test pressures. The total use of analytical approaches decreased from 45.6 % to 37.0 % from 2000-2004 to 2005-2008.[10] On the other hand, synthetic methods investigate mixtures with known composition without analysis of phases. Figure 2-5 B shows the detection of phase transitions using the synthetic approach with either visual or non-visual techniques. For visual methods, the fluid phase change is conducted in a pressure-volume-temperature (PVT) cell and visualized through a transparent window. More details of PVT tests are described in Section 2.2.1. For non-visual methods, a representative approach is to characterize the P-V curve where a sharp slope change indicates a phase change. More non-visual methods are grouped into optical (Section 2.2.2) and electrical methods (Section 2.2.3). This chapter also reviews microscale phase measurement techniques (Section 2.2.4) as well as emerging nanoscale methods (Section 2.2.5).
2.2.1 PVT experiments
It is essential to characterize the phase behavior of fluids in many industries. The oil and gas industry is the largest current application area for such measurements, from production to the refinery, to the consumer (upstream, midstream and downstream). Typically, upstream reservoir pressures range from 10 to 200 MPa and temperature ranges from 25 to 200 °C. Routine Pressure-Volume-Temperature (PVT) experiments are designed to emulate the processes in a reservoir produced through natural depletion, or “primary recovery”. One of the most important PVT properties is the saturation pressure at reservoir temperature.[9] For example, when pressure drops below the saturation pressure during production, the fluid will split into gas and liquid phases. However, the gas phase will be produced relatively easier compared to liquid due to lower viscosity and buoyancy, which leaves the heavier (often more valuable) components in the reservoir. Enhanced oil recovery (EOR) PVT experiments are performed with the goal to keep production in single phase with a high concentration of heavier components.
Figure 2-6 A lists the volume, pressure limit and temperature limit of PVT cells used for oil and gas condensate. The typical volume of a PVT cell is from 500 to 650 mL.[9] It is noteworthy that there are PVT cells can reach higher temperature than the ones in this table. For example, a PVT cell from Core Laboratories is rated at 260 oC. In industry, routine PVT experiments include constant-mass expansion, differential liberation and constant-volume depletion.
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Figure 2-6. Typical PVT experiments of a reservoir fluid. A) Pressure, volume and temperature conditions of PVT cells used for different reservoir fluids; Schematics of constant-mass expansion experiment for B) an oil mixture and C) a gas condensate; D) Schematics of differential depletion experiment for oil; E) Schematics of constant-volume depletion experiment for a gas condensate. Reproduced with permission from Taylor & Francis Group,[9] copyright 2015.
During the constant-mass expansion of an oil mixture (Figure 2-6 B), the oil mixture is initially stabilized at constant temperature and above reservoir pressure. The volume is increased so that pressure is decreased to the bubble point. The volume is decreased slowly. Pressure and volume are recorded at each time interval. Isothermal compressibility is calculated if the pressure is
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above saturation pressure, while the Y-factor (a ratio between the relative change in pressure and the total volume change in the two-phase region) is calculated below the saturation point. For the case of the constant-mass expansion of gas condensate (Figure 2-6 C), liquid is condensed when pressure is slowly decreased, down to a typical level of 5 MPa. The gas compressibility and liquid dropout are two parameters calculated from recorded data for the cases above saturation pressure and below saturation pressure, respectively. The differential liberation (Figure 2-6 D) best emulates the compositional and volumetric changes during oil production. The oil mixture is initially kept at a fixed reservoir temperature and above the reservoir pressure. The valve on top allows the gas to be depleted at constant pressure during pressure reduction. The depleted gas composition is measured at standard conditions. The pressure reduction and gas depletion are repeated typically six stages down to atmospheric pressure. Typically, the following parameters can be calculated: (1) formation volume factor Bo (the ratio of oil volume at certain stage to residual oil volume); (2) gas/oil ratio (GOR); and (3) gas formation volume factor (gas volume at cell condition over that at standard conditions). Another common PVT test is the constant- volume depletion, usually performed on gas condensate mixtures (Figure 2-6 E). In this test, the excess volume of gas on top during expansion is depleted to maintain a constant volume. This procedure is typically repeated six stages down to around 5 MPa. Liquid volume, compressibility factor, gas composition and other parameters can be measured.[9]
In summary, current PVT methods are the standard technique of fluid phase analysis because they offer direct visual quantification of fluid phases, precise control of temperature and pressure, and are the incumbent technology in the oil and gas industry. Commercial PVT systems can be used to measure not only saturation pressure and temperature, but also other properties including viscosity, gas-oil-ratio, density and chemical composition (with chromatography tools). However, a typical PVT system usually takes hours to change temperature for a new data point due to a large heat mass associated with a bulky cell volume (hundreds of mL). On the side of cost, the PVT visualization cell along with complicated accessories, such as temperature-, pressure- and control-system, can cost up to $500,000. The slow measurement times and the high capital costs motivate innovation in this space - novel fluid phase measurement techniques, such as optical, electrical, acoustic or microfluidic methods, targeting specific applications.
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2.2.2 Optical methods
Figure 2-7. Optical methods: A) Schematics of automatic chilled mirror method;[28] B) Principle of Tunable Diode Laser Absorption Spectroscopy (TDLAS);[29] C) Schematics of Fabry-Perot hygrometer; [28] D) Schematics of fiber-optic reflectometer;[30] Reproduced with permission from GE Measurement & Control, Ametek Process Instruments, and, AIP Publishing LLC, copyright 2006.
Fluid phase change can be measured by the means of optical signals. Several principles of optical methods are briefly discussed here. Chilled mirror method measures the dew point temperature by using a cooled plane surface to induce condensation. The dew formation is detected manually by eye (details can be found in ASTM-1142) or automatically by an optical system. In the
18 automatic approach (See Figure 2-7 A), visible or IR light is emitted from a photodiode, reflected from the cooled mirror surface and received by the photodetector. Once dew is formed, the reflected light is modified due to the absorption and scattering of incident light. The range of a typical chilled mirror is from -80 to 85°C.[28] It is noteworthy that the chilled mirror method is widely accepted as a laboratory reference standard for calibration purposes. Absorption spectroscopy is another approach that uses optical signals to interpret fluid phase change, especially dew point (See Figure 2-7 B). Tunable laser diode offer a broad bandwidth of spectrum to include vibration frequency that is unique to the species of molecule detected. The spectroscopy measurement is based on the non-contact method, which is a distinct advantage. However, the measurement result is very sensitive to the temperature of the laser diode, which should be taken care of in measurements.[29] Other examples using an optical method for dew point detection are based on refractive index sensing, such as the Fabry-Perot hygrometer and Fiber-optic reflectometer. The Fabry-Perot hygrometer (See Figure 2-7 C) consists of multi- layered material with high and low refractive indices. The condensed liquid (usually water) inside the surface material layer changes the refractive index and shifts the signal wavelength. The wavelength shift is proportional to the amount of liquid molecules on the sensor. This technique provides intrinsically safe light signals but has the disadvantage of slow response and coating degradation after long-term use.[28] The fiber-optic reflectometer (See Figure 2-7 D) detects the change in the fluid by responding to the difference in refractive indices between the fiber material and the fluid residing on the end of fiber. This fiber-optic sensor can detect bubble point, dew point and critical point via the reflected signal. The fiber-optic probe installed in an equilibrium cell can work at high temperatures (300 °C) and pressures (30 MPa).[30] Importantly, optical methods have been employed with conventional PVT system, e.g., Solid Detection System (Schlumberger) which measures the saturation/onset pressure by NIR light transmission and Charged-Coupled Device system (Schlumberger) which measures the fluid volume via a movable long-distance microscope.
In summary, optical methods offer several advantages, such as high sensitivity, in situ measurement, automatic detection and potential for distributed sensing over long distances. A wide application of optical methods is the measurement of moisture or dew point of industrial gas especially for CO2 and natural gas.
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2.2.3 Electrical and acoustic methods
Figure 2-8. Electrical methods: A) Capacitance probe and operating principle; B) Quartz- crystal microbalance (QCM) sensors and operating principle.[29] Reproduced with permission from Ametek Process Instruments, copyright 2011.
Electrical methods utilize electrical signals to detect dew or moisture content. This subsection reviews a few typical electrical methods including capacitance-based and oscillation-based approaches. A capacitance probe (Figure 2-8 A) generally uses moisture-sensitive dielectric material sandwiched between two electrodes. The condensed liquid (typically water) changes the dielectric constant of the layer material. The change in capacitance is detected by an electrical circuit. This approach has the advantage of a low installation costs but is vulnerable to contamination or fouling from system impurities. A quartz crystal microbalance (See Figure 2-8 B) employs mechanical oscillation to detect the fluid phase transition. The condensed liquid on the coating material increases the mass loading of the oscillator which decreases the resonance frequency. The amount of condensation is related to the oscillation frequency. It is noteworthy that the quartz crystal microbalance is widely used in natural gas moisture measurement in industry because of its high accuracy (down to 10 ppb). Determining fluid phase change by tracking mass change is also the principle of a surface acoustic sensor. A surface acoustic wave sensor was developed to quantify water condensation and dew point.[31] The pioneer work
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shows a sensitivity that a phase shift of 30° is equivalent to 3µg/cm2. The sound speed in a fluid is another parameter of fluid phases. In a previous work, the phase behavior of rich gas mixtures (varying methane from 70 to 82 %, up to 22 MPa) were measured by the decompression wave.[32] The change in the speed of sound within a fluid indicates the fluid phase transition. The change in the decompression wave speed between dry gas and the two-phase region agreed with the model predictions within a few percent.
In summary, electrical and acoustic methods take advantages of the changes in electrical or acoustic signals caused by a new phase during phase transition. Capacitance sensors are widely used in the measurement of moisture or dew point of natural gas due to relative low cost.
2.2.4 Microfluidic methods
Microfluidic technologies offer unique perspectives and tools for fluid phase measurement. The inherent advantages provided by microfluidics include small sample volume, precise control of temperature and pressure, time-efficient operation, fast analysis and potential for multiplexing. This subsection reviews microfluidic-based methods for fluid phase measurement.
A microfluidic PVT system was first developed by Mostowfi et. al.[11] The silicon-glass bonded microfluidic device allows direct visualization within a flow-based design. The idea is to establish a pressure-driven steady liquid flow in a long serpentine channel and induce bubble formation at designed inlet restrictions, as shown in Figure 2-9 A and B. The generated bubbles expand as they flow downstream where the gas-liquid volume fraction is measured, as shown in Figure 2-9 C. The experiment is performed at room temperature. Inlet pressure is set slightly above the saturation pressure and the outlet pressure is set at atmospheric pressure. Micro-cavity- based pressure sensors along the microchannel are used to indicate the pressures by measuring the deformation of cavities. Phase change is imaged using a high speed camera operating at 5000 fps. The detected bubble point pressure shows a ± 2.5 % relative accuracy. A linear pressure drop was observed in the liquid-gas slug flow. Notably, this approach requires less than 15 minutes, compared to 8 hours using conventional PVT techniques. This pioneer work introduced a microfluidic approach to PVT studies, specifically bubble point pressure determination. This PVT system was also used to determine the gas-oil-ratio of hydrocarbons in a later study.[33] Mostowfi’s team also developed a microfluidic platform to measure asphaltene of crude-oil
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samples, which took less than 30 minutes (compared to days required for the conventional technique) and showed good repeatability of ± 2%.[34]
Figure 2-9. A microfluidic PVT system. A) Concept of bubble point measurement: bubble forms below bubble point pressure at the inlet restriction. B) Image sequence of bubble evolution at the inlet restriction (5000 fps). C) Image of the microfluidic PVT system in operation, showing bubble and liquid slugs. Reproduced with permission from Royal Society of Chemistry,[11] copyright 2012.
Later, another microfluidic device with serpentine channel was developed by Aymonier et. al to measure the bubble point, dew point and critical point of a multicomponent system, as shown in Figure 2-10 A and C.[35] The silicon-glass material allows direct visualization, high temperature and high pressure capabilities. The primary advantage here, as compared to Mostowfi’s PVT device, is that it can detect dew point and critical point in addition to bubble point pressure. This device can function at higher temperature (300 - 500 K) and higher pressure (1 - 200 bar). Finally, this device offers a distinct operational mode (“dynamic stopflow” via a bypass channel, see Figure 2-10 B) which can reduce the flowrate significantly and therefore lower the requirement camera imaging speed using 4 fps rather than 300 fps using a continuous mode. The measurement demonstrated a 2 % deviation from modeling results. This microfluidic approach is 5 times faster than conventional optical cell methods.
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Figure 2-10. A microfluidic system investigating thermodynamics at high pressures and temperatures. A) Schematics of the microfluidic system with the key features of the serpentine channel. B) Analogy of two operation modes: “continuous flow” and “dynamic stopflow mode”. C) Measurement of phase envelop with detected bubble point and dew point. Reproduced with permission from Royal Society of Chemistry,[35] copyright 2014.
Recently, more microfluidics-based techniques have been developed for the phase behavior measurement of multicomponent samples. Sinton et. al. developed a microfluidic chip to measure trace amount (~ 10 µL and <0.005 mole fraction) of water droplet in industrial CO2 streams, as shown in Figure 2-11 A.[36] The glass microfluidic chip enables direct visualization of dew droplet (1 – 2 µm) under high pressure, up to 13 MPa. This microfluidic approach provides a 3-fold error reduction compared to existing methods. Sinton group made another microfluidic device to measure minimum miscibility pressure of CO2 in crude oils, as shown in
Figure 2-11 B. The CO2 phase and the oil phase are clearly distinguished by the inherent fluorescence of crude oil. The miscibility pressure can be determined by investigating the
intensity profile across interface between CO2 and crude oil, which is automatic and operator independent. The variation of results by using this technique is 0.5 MPa which is lower than for
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conventional methods (e.g. the rising bubble approach). Importantly, this method takes less than 30 minutes in contrast to the days or weeks by using conventional methods.[37]
Figure 2-11. Two microfluidic systems measuring the phase behavior of multicomponent samples. A) Detection of water dew point in CO2 stream. B) Measurement of the minimum
miscibility pressure of CO2 in crude oils. Reproduced from American Chemical Society, [36][37] copyright 2014 and 2015.
In summary, microfluidic methods exhibit inherent advantages of low sample volume and time- saving operations and analysis over conventional PVT methods. In addition, microfluidic based measurement usually is coupled with precise control of temperature and pressure which provides accurate measurement. Notably, microfluidic (chamber or channel is smaller than 1 mm) or even meso-fluidic (chamber or channel is between 1 mm and 1 cm) present a great potential for multiplexing of multiple parameters into a single run, which could significantly reduce operation time and cost. The challenges of commercialization of the microfluidic-based methods come from fabrication cost and the relative short lifetime due to contamination and mechanical weakness for long-term run.
2.2.5 Nanofluidic methods
In the previous subsection, it was shown that microfluidic methods are mostly motivated by improving the time efficiency of fluid phase measurements. In other words, the microfluidic
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systems are targeting for practical applications and competing with existing techniques. In contrast, the phase behavior measurements at the nanoscale are mostly motivated by understanding the fundamental physics of the effect of nano-confinement in phase transition. This subsection summarizes the experimental investigation of fluid phase change in nano- confinement.
Buongiorno et. al. measured the water nucleation temperature on nanoscale cavities (down to 90 nm in diameter) and posts (down to 60 nm in diameter) fabricated on ultra-smooth silicon wafers, as shown in Figure 2-12 B. A lamp is used to heat the water-inducing bubble nucleation on the surface. The temperature of the surface is measured by using an infrared camera (650 to 1000 fps) with an accuracy of 2°C, as shown in Figure 2-12 A. Bubble nucleation is indicated by a sudden temperature drop. This technique showed that the bubble nucleation happens at a high superheating condition and agrees with the curve predicted by a Young-Laplace model, as shown in Figure 2-12 C. This result provides solid evidence that bubble nucleation in nano-sized features is not happening at the saturation temperature.
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Figure 2-12. Study of bubble nucleation by a local heating source. A) Schematics of experimental setup for boiling on surfaces with fabricated cavities and posts; B) Enlarged images of cavities and posts; C) Experimental data of water boiling temperature in experimental conditions and theory predictions. Reproduced with permission from American Institute of Physics, [38] copyright 2012.
The nanoscale confinement is not limited to single geometries of cavity or post. Nanochannels represent another geometry that can be fabricated and applied to study the fluid phase transition. Majumdar et. al. observed evaporation-induced cavitation in nanofluidic channels.[23] Cavitation is defined as the bubble formation in liquids which is under tension, or, understood as the bubble formation at pressures lower than saturation pressure at given temperature. Liquid water is filled in 58-nm nanochannel as well as the connecting microchannels, as shown in Figure 2-13 A. Instead of evaporation (receding liquid-vapor menisci), a vapor bubble is “swallowed” into nanochannel followed by liquid slug pinning at nanochannel entrance, as shown in Figure 2-13 B. Such evaporation-induced cavitation was explained as the presence of
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local expansions at the nanochannel entrance. In other words, the expansion at the entrance is responsible for the entrapped bubble that subsequently moved into center, as shown in Figure 2- 13 C. This study provides new insights into fluid phase change at the nanoscale.
Figure 2-13. A) Nanochannel device including sets of nanochannels; B) Cavitation induced by deformed meniscus and bubble entrapment at the nanochannel entrance; C) Image sequence of cavitation in 58-nm nanochannels. Reproduced with permission from Proceedings of the National Academy of Sciences of the United States of America,[23] copyright 2012.
Fluid phase change in nanoscale was also investigated in a nanoporous medium. A porous silicon (poSi) layer with ink-bottle geometry was developed by Stroock et. al. and applied to the study of the drying process by cavitation.[39] The layer including nanoscale pores of 1-2 nm in radius is under the glass layer with arrays of micro voids, as shown in Figure 2-14 A and B. The system of 625 voids is filled with water and dried for 60 h. The drying dynamics were visualized and it was observed that evaporation started from all four edges, as shown in Figure 2-14 C. The cavitation pressure was found to be 84 % of saturation pressure.
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Figure 2-14. Cavitation test of water in nano-porous media. A) Top view and B) Side view schematics of ink-bottle structure filled with water; Porous silicon (poSi) is interconnected to these cavities; C) Optical images show evaporation occurred from edges of sample. Reproduced with permission from American Physical Society, [39] copyright 2014.
The research of fluid phase behavior in nanoconfinement is becoming of high interest, and is largely driven by the rise of shale gas/oil production in recent years. The lack of experimental investigations in this field motivates the research of hydrocarbon phase behavior in nanopores. A nanofluidic device including a set of nanochannels was made by Ma and Yin et. al. to study both the transport of water/gas system at the nanoscale as shown in Figure 2-15 A, B and C.[20] By using the same device, Yin and Ozkan studied the liquid-to-vapor phase transition of pure n- pentane, and, a ternary mixture of n-butane, i-butane and n-octane.[26] It was found that pure hydrocarbons evaporated immediately after the complete drying in the service microchannel, as shown in Figure 2-15 D. However, the evaporation of the ternary mixture stopped before entering nanochannels due to the distillation effect which leaves heavier components during continuous evaporation, as shown in Figure 2-15 E. Improvements in experimental design are needed for mixtures to avoid the distillation effect which changes the composition of liquid.
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Figure 2-15. Study of nanoconfinement effect in hydrocarbon production. A) Structure of nanofluidic chip; B) SEM image of nanochannels; C) Experiment of water displacing nitrogen gas; D) Pentane evaporation in nanochannels; E) Evaporation of a ternary mixture stopped in one of the microchannels. Reproduced with permission from Society of Petroleum Engineers,[20][26] copyright 2014.
In summary, nanofluidic systems (chamber or channel is smaller than 1 µm) for fluid phase measurement are mostly motivated by understanding the nano-scale confinement effect in phase transition phenomenon such as boiling, cavitation and condensation. Literature shows that the nano-scale confinement brings in some unique phenomena, such as extreme high boiling temperature (super heating), which is different from that in bulk volume. The application of these nanofluidic methods can be extended to investigate more fundamental physics involved in nanoscale related applications, such as Shale/tight oil production. On the other hand, the constraints in nanofluidic methods are mostly associated with the complicated fabrication process, high cost and mechanical weakness due to contamination and clogging. More research effort is needed to overcome these constraints.
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3 Detection of Bubble and Dew Point using Optical Thin-film interference
Bubble and dew point data are essential for many practical applications, and particularly the safe
pipeline transport of post-capture CO2 which contain impurities. These mixtures show highly composition-specific phase properties, necessitating much more experimental data and motivating more rapid and inexpensive measurement methods. Here we demonstrate a responsive small-scale pressure-volume-temperature (PVT) cell system enabled by thin-film interference, and its application to an industrially-relevant post-capture CO2 mixture stream. The small (5 mL) volume is one-to-two orders of magnitude faster to equilibrate than conventional PVT cells with viewing windows. Inside the cell, top and bottom optical fiber sensors detect bubble and dew points, respectively. At vapor-liquid transition points, the reflection spectrum from the optical fiber tips report clear interference patterns caused by a thin film on the sensor. In addition to sharply delineating the phase change condition, the sensor also reports the real time thickness of the film (accuracy on the order of 1 µm). The method is validated with the well
characterized pure CO2 test case (average error of 2.8 bar as compared to NIST data), and
applied to an industrially-relevant CO2 stream, characteristic of post-capture oxyfuel combustion
– an important source for downstream CO2 utilization and storage.
Bao, B., Fadaei. H., Sinton. D. Detection of Bubble and Dew Point Using Optical Thin-Film Interference. Sensors & Actuators: B. Chemical, 207 (A) 640–649 (2015). Reproduced with permission from Elsevier.
Publication online link: http://www.sciencedirect.com/science/article/pii/S0925400514012878
3.1 Introduction
Fluid phase behavior at high pressures is central to a wide range of processes including petroleum reservoir engineering, high-pressure chemical reactors, and transport and storage of
natural gas and CO2.[40] Phase behavior of CO2 is of much interest due to concerns over global
CO2 emissions and related industrial applications in enhanced oil recovery and carbon
sequestration. Pipeline transport of CO2 is central to all current and eventual large-scale CO2
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applications.[41] Effective transport requires that CO2 remains in a dense phase (either liquid or supercritical), and thus measurement and knowledge of the phase behavior of industrially-
relevant CO2 is essential.
In contrast to laboratory grade CO2, industrially-relevant CO2 streams contain a variety of
impurities, often including N2, O2, Ar, CO, H2O, SOx, NOx, H2S and other components depending on the source process.[42] Typical sources include power plants, refineries,
upgraders, cement plants and steel plants. The presence of impurities in the CO2 stream significantly impacts the phase behavior, as indicated by current models.[43][44][45][46] For instance, phase diagrams of CO2 and N2 binary mixtures studied by Equation of State models
show significant deviation from pure CO2 phase behavior (e.g. a 40% increase in saturation
pressure at 0°C of CO2 with 5 mol % N2).[43] In another approach, a ternary mixture of N2, O2 and CO2 at low temperature was modeled by combining experimental data from the three binary subsystems.[44] In general models indicate that even relatively low concentrations of air-
derived impurities (N2, O2 and Ar) can considerably increase the saturation pressure and decrease
the critical temperature of CO2 streams.[43][45] The implications for transport are particularly significant. Maintaining a dense phase will require either lower temperatures (generally not feasible), or increased pressures leading to increased capital and operating costs.
Current methods of measuring fluid phase transition include analytical (~ 40%) and synthetic (~ 60%) approaches.[40] In analytical methods, fluid is sampled from both phases of an equilibrium mixture and the composition of each phase is measured using chromatography or spectroscopy.[47][48] Challenges include sampling an equilibrium mixture without significantly disrupting the equilibrium, and relatively high capital and labor costs. Synthetic approaches can determine phase behavior of prepared mixtures with known compositions without sampling.[40] Synthetic-visual techniques are the most common methods, involving a pressure-volume- temperature (PVT) cell with a visualization window which allows direct observation of phase transition as a function of cell pressure and temperature.[49][50] Synthetic-nonvisual experimental methods have also been developed, using acoustics,[51][31] quartz sensors[52][53][54] and infrared spectroscopy.[55]
Microfluidic-based PVT devices were developed to measure physical properties such as diffusivity of immiscible fluid mixtures, showing orders of magnitude improvement in speed and
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sample volume.[56][57] Another microfluidic PVT approach was developed to analyze phase diagrams of vapor-liquid systems.[11] The depressurization of the sample as it flowed through the microfluidic chip mimicked the fluids transition from reservoir to surface. Recently we developed a microfluidic approach to detecting liquid water condensation at very low
concentrations in supercritical CO2 using direct observation.[58] A localized surface plasmon resonance based sensor was demonstrated to detect dew condensation on gold/ceramic nanocomposite.[59] To enable more accurate and automated optical detection, optical fibers are a preferred approach. We have previously developed ultra-sensitive optical fiber sensors to detect
dissolved CO2 in brine at reservoir temperatures and pressures.[60] Optical fiber sensor has been used to determine relative humidity in air.[61] Reflection-based optical fiber sensors have also been applied to directly detect phase transition.[62][30] In general, optical fiber sensors offer many benefits for PVT related studies, including high accuracy, robustness, fast response, compact size and low cost.
The method presented in this chapter is a new synthetic-nonvisual approach which exploits the principle of thin-film interference on reflection-based optical fiber sensors. During vapor-liquid phase transitions, the reflection spectra of the optical fiber sensors show transient interference patterns caused by accumulation of thin films of vapor or liquid phase on the sensor. This new
PVT system was first applied to determine the vapor-liquid phase transition of pure CO2 - enabling validation of the technique. Then, the phase transition envelope for an industrially- relevant CO2 stream from oxyfuel combustion was measured. The experimental result – a first – was compared with predictions from two common models.
3.2 Experimental
3.2.1 Experimental setup
The schematic of experimental apparatus is shown in Figure 3-1 a. A cross-shaped PVT cell was connected to a high-pressure syringe pump (Teledyne ISCO Model 260D) and a cylinder containing CO2 samples. Optical fibers sensors were inserted both at the top and bottom of the PVT cell. The temperature of the PVT cell was controlled by emersion in a water bath (Polystat Cooling/Heating Circulating Bath, 6.5 L), while the pressure was controlled by the pump. The two optical fiber sensors were connected with an optical interrogator (Micron Optics SM 125).
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The optical interrogator delivered a broadband incident light (1510 – 1590 nm) to each of the optical fiber sensors and detected the spectra of reflected light from the sensors in real time.
The internal features of the PVT cell are shown in Figure 3-1 b. The stainless steel PVT cell had an internal volume of about 5 mL and four 1/8” NPT ports. The left and right ports allowed loading and purging the fluid samples, respectively. The top and bottom ports immobilized the top and bottom optical fiber sensors, respectively. The optical fiber sensor was single mode (Core/Cladding/Coating: 9/ 125/ 245 µm). One distal end of the fiber was cleaved to generate a flat fiber tip to serve as the reflection sensor surface. The other distal end was connected to the interrogator. The top and bottom fiber tips were positioned axially to be just inside the fluid cavity of the PVT cell. The optical fiber was sealed with a PEEK sleeve and compression fittings, as detailed elsewhere.[60]
Figure 3-1. a) Schematic of experimental apparatus integrating gas cylinder, pump, PVT cell, optical interrogator, and computer; b) Internal features of the PVT cell with optical fiber sensors.
3.2.2 Sensing mechanism: thin-film interference
Figure 3-2 shows the principle of detection of vapor-liquid phase transition with a fluid sample. If the fluid sample surrounding the fiber tip exists as a single phase (Figure 3-2a), such as single vapor or liquid phase, the incident light travelling inside the fiber core will be partially reflected at the fiber/fluid interface. The reflection light intensity is a function of refractive index of the
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fluid sample near the end of the fiber. This single-phase reflection mode is the previous approach to phase detection with reflection-based optical fiber sensors. [62][30]
Figure 3-2. a) Schematic of single phase fluid surrounding the fiber tip; b) , i.e. Schematic of a liquid film on fiber tip while surrounding medium is vapor phase, i.e., Phase I = liquid, Phase II = vapor. Thin-film interference is an additive effect of a wave reflected at the Core/Phase I interface (dotted curve) and a wave reflected at the Phase I/Phase II (dashed curve). No phase shift results in a constructive wave returning to the detector, where as a 180° wave phase difference returns a destructive wave. Thus, the presence of thin film – indicating vapor-liquid phase transition - can be very accurately determined by the optical fiber sensor via constructive and destructive wave patterns in the reflection spectrum. It is also possible to extract further measurements from this returning signal, such as film thickness.
Figure 3-2b shows the thin-film approach developed in this work. Specifically, in dew-point detection, any liquid forming (from an otherwise gaseous mixture) forms preferentially at the bottom of the PVT cell, and is subsequently detected by the bottom optical fiber sensor. Both types of phase transitions (dew-point and bubble-point) can exhibit temporary thin films on the
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sensor surface. In the case of dew formation, a thin layer of liquid film would be condensed on the fiber tip while the surrounding medium is still in vapor phase (Figure 3-2b). In the case of bubble formation, either a thin vapor film or a thin liquid film is possible during transition, depending on the wettability of the sensor (typical silica fibers are highly hydrophilic and thus liquid films are expected during transition). Thin films on the end of the fiber optic generate interference as shown at right in Figure 3-2b. Constructive interference, as shown, is an additive effect of a wave reflected at the first interface (dotted curve) and a wave reflected at the second interface (dashed curve). Specifically, the two reflected waves have the same electromagnetic wave phase (the term ‘EM phase’ is used here to distinguish from vapor/liquid ‘phase’). In contrast, if the reflected waves have an EM phase difference of 180°, the added wave will show a destructive wave pattern. The thin-film interference can be clearly identified by the reflection spectrum as a function of wavelength. This interference will also be accompanied by a change in the average reflected power. For instance, in the case where a liquid film is replaced by gas (bubble point detection), the reflected power will increase.
In addition to measuring vapor-liquid phase transition, the interference pattern also enables the determination of the thickness of the liquid film on the fiber tip. Considering the principle of thin-film interference demonstrated by Figure 3-2b, the wavelength associated with the constructive wave in the thin film is λ1, while the wavelength associated with the neighbor
destructive wave in the thin film is λ2 (λ2>λ1). The thickness of the liquid film on fiber tip, d, is correlated to the wavelength by Eq 3-1, where m is an even integer.