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- Herausgeber: John Wiley & Sons
- Kategorie: Wissenschaft und neue Technologien
- Serie: Advances in Natural Gas Engineering
- Sprache: Englisch
This is the sixth volume in a series of books on natural gas engineering, focusing carbon dioxide (CO2) capture and acid gas injection. This volume includes information for both upstream and downstream operations, including chapters on well modeling, carbon capture, chemical and thermodynamic models, and much more. Written by some of the most well-known and respected chemical and process engineers working with natural gas today, the chapters in this important volume represent the most cutting-edge and state-of-the-art processes and operations being used in the field. Not available anywhere else, this volume is a must-have for any chemical engineer, chemist, or process engineer working with natural gas. There are updates of new technologies in other related areas of natural gas, in addition to the CO2 capture and acid gas injection, including testing, reservoir simulations, and natural gas hydrate formations. Advances in Natural Gas Engineering is an ongoing series of books meant to form the basis for the working library of any engineer working in natural gas today. Every volume is a must-have for any engineer or library.
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Contents
Cover
Title page
Copyright page
Preface
Chapter 1: Enthalpies of Carbon Dioxide-Methane and Carbon Dioxide-Nitrogen Mixtures: Comparison with Thermodynamic Models
1.1 Introduction
1.2 Enthalpy
1.3 Literature Review
1.4 Calculations
1.5 Discussion
1.6 Conclusion
References
Chapter 2: Enthalpies of Hydrogen Sulfide-Methane Mixture: Comparison with Thermodynamic Models
2.1 Introduction
2.2 Enthalpy
2.3 Literature Review
2.4 Calculations
2.5 Discussion
2.6 Conclusion
References
Chapter 3: Phase Behavior and Reaction Thermodynamics Involving Dense-Phase CO
2
Impurities
3.1 Introduction
3.2 Experimental
3.3 Results and Discussion
References
Chapter 4: Sulfur Recovery in High Density CO
2
Fluid
4.1 Introduction
4.2 Literature Review
4.3 Methodology
4.4 Results and Discussion
4.5 Conclusion and Future Directions
References
Chapter 5: Carbon Capture Performance of Seven Novel Immidazolium and Pyridinium Based Ionic Liquids
5.1 Introduction
5.2 Experimental Work
5.3 Modeling
5.4 Results and Discussion
5.5 Conclusion
Acknowledgements
References
Chapter 6: Vitrisol
®
a 100% Selective Process for H
2
S Removal in the Presence of CO
2
6.1 Introduction
6.2 Case Definition
6.3 “Amine-Treated” Cases by PPS
6.4 Vitrisol
®
Process Extended with Regeneration of Active Component
6.5 Results
6.6 Discussion
6.7 Conclusions
6.8 Notation
References
Appendix 6-A: H&M Balance of Case 1 (British Columbia shale) of the Amine Process
Appendix 6-B H&M Balance of Case 2a (Barnett shale) of the Amine Process with Stripper Promoter
Appendix 6-C H&M Balance of Case 3 (Barnett shale) of the Amine Process (MEA)
Appendix 6-D: H&M Balance of Case 1 (British Columbia shale) of the Vitrisol
®
process
Appendix 6-E H&M Balance of Case 2 (Barnett shale) of the Vitrisol
®
Process
Chapter 7: New Amine Based Solvents for Acid Gas Removal
7.1 Introduction
7.2 Chemicals and Materials
7.3 Liquid-Liquid Equilibria
7.4 Densities and Heat Capacities of Ternary Systems {NMPD – H
2
O – Glycol}
7.5 Vapor-Liquid Equilibria of Ternary Systems {NMPD – TEG – H
2
O – CO
2
}
7.6 Enthalpies of Solution
7.7 Discussion and Conclusion
Acknowledgments
References
Chapter 8: Improved Solvents for CO
2
Capture by Molecular Simulation Methodology
8.1 Introduction
8.2 Physical and Chemical Models
8.3 Molecular-Level Models and Algorithms for Thermodynamic Property Predictions
8.4 Molecular-Level Models and Methodology for MEA–H
2
O–CO
2
Acknowledgements
References
Chapter 9: Strategies for Minimizing Hydrocarbon Contamination in Amine Acid Gas for Reinjection
9.1 Introduction
9.2 Amine Sweetening Process
9.3 Hydrocarbons in Amine
9.4 Effect of Hydrocarbons on the Acid Gas Reinjection System
9.5 Effect of Hydrocarbons on the Amine Plant
9.6 Minimizing Hydrocarbon Content in Amine Acid Gas
References
Chapter 10: Modeling of Transient Pressure Response for CO
2
Flooding Process by Incorporating Convection and Diffusion Driven Mass Transfer
10.1 Introduction
10.2 Model Development
10.3 Results and Discussion
10.4 Conclusions
Acknowledgments
References
Chapter 11: Well Modeling Aspects of CO
2
Sequestration
11.1 Introduction
11.2 Delivery Conditions
11.3 Reservoir and Completion Data
11.4 Inflow Performance Relationship (IPR) and Injectivity Index
11.5 Equation of State (EOS)
11.6 Vertical Flow Performance (VFP) Curves
11.7 Impact of the Well Deviation on CO
2
Injection
11.8 Implication of Bottom Hole Temperature (BHT) on Reservoir
11.9 Impact of CO
2
Phase Change
11.10 Injection Rates, Facility Design Constraints and Number of Wells Required
11.11 Wellhead Temperature Effect on VFP Curves
11.12 Effect of Impurities in CO
2
on VFP Curves
11.13 Concluding Remarks
Conversion Factors
References
Chapter 12: Effects of Acid Gas Reinjection on Enhanced Natural Gas Recovery and Carbon Dioxide Geological Storage: Investigation of the Right Bank of the Amu Darya River
12.1 Introduction
12.2 The Amu Darya Right Bank Gas Reservoirs in Turkmenistan
12.3 Model Development
12.4 Simulation Model
12.5 Results and Discussion
12.6 Conclusions
12.7 Acknowledgments
References
Index
End User License Agreement
Guide
Cover
Copyright
Contents
Begin Reading
List of Tables
Chapter 1
Table 1.1
Summary of experimental data of enthalpy of carbon dioxide mixtures.
Table 1.2
Absolute average difference in excess enthalpies for methane and nitrogen mixtures using the different models.
Table 1.3
Absolute average error in excess enthalpies for methane and nitrogen mixtures using the different models.
Table 1.4
Absolute average difference in enthalpy departure for methane mixtures using the different models.
Table 1.5
Absolute average error in enthalpy departure for methane mixtures using the different models.
Chapter 2
Table 2.1
AAD, AAE, maximum difference and maximum error using the six different thermodynamic models for the hydrogen sulfide-methane mixture
Chapter 3
Table 3.1
Chemical name, purities, source and analysis method.
Table 3.2
Impurity concentrations in CO
2
and the conditions studied.
Table 3.3
The Helmholtz EOS model used to describe the pure component fluid.
Chapter 5
Table 5.1
Characteristics of ionic liquids used in this work.
Table 5.2
Temperature-dependent density correlations for the studied ionic liquids.
Table 5.3
Critical properties of ionic liquids.
Table 5.4
Henry’s law constants and enthalpies and entropies of absorption for CO
2
in the studied ionic liquids [17, 18].
Table 5.5
Standard deviations PR-EoS for the ionic liquids + CO
2
system.
Chapter 6
Table 6.1
Case Specifications.
Table 6.2
Case specifications.
Table 6.3
Utility consumptions of cases 1 and 2 of the amine process.
Table 6.4
Utility consumptions of Cases 1 and 2 of the Vitrisol
®
process.
Table 6.5a
Absorber and stripper dimensions.
Table 6.5b
Utility Consumptions of Cases 2b and 3 of the Amine Process.
Table 6.6
Utility consumptions of cases 1 and 2 of the amine process.
Table 6.7
Utility consumptions of cases 1 and 2 of the Amine process.
Chapter 7
Table 7.1
Suppliers, CAS numbers and stated purities (mass fraction w) of chemicals used in this study.
Table 7.2
Characteristics of the visual cells used for cloud point measurements.
Table 7.3
Composition of the ternary systems {NMPD – H
2
O – TEG} and temperature range investigated in the density study.
Chapter 9
Table 9.1
Hydrocarbon reduction case study.
Chapter 10
Table 10.1
Physical properties and operating conditions of the base case.
Chapter 11
Table 11.1
Reservoir and completion data.
Table 11.2
Critical points of the cases considered.
Chapter 12
Table 12.1
Physical reservoir properties.
Table 12.2
The differences of the nine development models.
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Scrivener Publishing100 Cummings Center, Suite 541JBeverly, MA 01915-6106
Publishers at ScrivenerMartin Scrivener ([email protected])Phillip Carmical ([email protected])
Carbon Dioxide Capture and Acid Gas Injection
Edited by
Ying Wu
John J. Carroll
Weiyao Zhu
This edition first published 2017 by John Wiley & Sons, Inc., 111 River Street, Hoboken, NJ 07030, USA and Scrivener Publishing LLC, 100 Cummings Center, Suite 541J, Beverly, MA 01915, USA© 2017 Scrivener Publishing LLCFor more information about Scrivener publications please visit www.scrivenerpublishing.com.
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Library of Congress Cataloging-in-Publication DataISBN 978-1-118-93866-9
Preface
The Sixth International Acid Gas Injection Symposium (AGIS VI) was held in Houston, Texas, in September 2016. As with previous Symposia, the focus of AGIS VI was the injection of acid gas (CO2, H2S, and mixtures of these components) for the purposes of disposal or for enhanced oil and/or gas recovery. This book contains select papers from the Symposium in Houston.
The capture of carbon dioxide from flue gas and its disposal into a subsurface geological formation remains a viable option for the clean use of hydrocarbon fuels. The related technology is acid gas injection. Here the H2S and CO2 are removed from raw natural gas. This volume contains papers directly related to these two topics ranging from the physical properties of the gas mixtures, evaluation of new and existing solvents, and subsurface engineering aspects of the process. Furthermore, contributors came from Canada, Europe, and China, as well as from the host country, the United States. And this is reflected in the papers in this volume.
On a very sad note, Marco Satyro passed away on September 8, 2016, just prior to the Symposium. Marco was a good friend of AGIS being an active member of the Technical Committee for many years. He contributed many papers and encouraged many others to participate. At the first AGIS he presented the paper “The Performance of State of the Art Industrial Thermodynamic Models for the Correlation and Prediction of Acid Gas Solubility in Water” and this paper appeared in the first volume of the Advances in Natural Gas Engineering. He also was the coauthor of several other contributions to the Series and they are listed below. This volume is dedicated to the memory of Dr. Satyro.
References – papers of M.A. Satyro from the Advances in Natural Gas Engineering series.
M.A. Satyro, and J. van der Lee, “The Performance of State of the Art Industrial Thermodynamic Models for the Correlation and Prediction of Acid Gas Solubility in Water”, pp. 21–34, Acid Gas Injection and Related Technologies, Y. Wu and J.J. Carroll (eds.), Scrivener Publishing (2011).
H. Motahhari, M.A. Satyro, and H.W. Yarranton, “Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation”, pp. 41–52, Carbon Dioxide Sequestration and Related Technologies, (2011), Y. Wu, J.J. Carroll, and Z. Du (eds.), Scrivener Publishing (2011).
J. van der Lee, J.J. Carroll, and M.A. Satyro, “A Look at Solid CO2 Formation in Several High CO2 Concentration Depressuring Scenarios”, pp. 117–128, Sour Gas and Related Technologies, Y. Wu, J.J. Carroll, and W. Zhu (eds), Scrivener Publishing (2012).
M.A. Satyro, and J.J. Carroll, “Phase Equilibrium in the Systems Hydrogen Sulfide + Methanol and Carbon Dioxide + Methanol”, pp. 99–109, Gas Injection for Disposal and Enhanced Recovery, Y. Wu, J.J. Carroll, and Q. Li (eds.), Scrivener Publishing (2014).
A.R.J. Arendsen, G.F. Versteeg, J. van der Lee, R. Cota, and M.A. Satyro, “Comparison of the Design of CO2-capture Processes using Equilibrium and Rate Based Models”, pp. 155–174, Gas Injection for Disposal and Enhanced Recovery, Y. Wu, J.J. Carroll, and Q. Li (eds.), Scrivener Publishing (2014).
M.A. Satyro and H.W. Yarranton, “A Simple Model for the Calculation of Electrolyte Mixture Viscosities”, pp. 95–104, Acid Gas Extraction for Disposal and Related Topics, Y. Wu, J.J. Carroll, and W. Zhu (eds.), Scrivener Publishing (2016).
Chapter 1Enthalpies of Carbon Dioxide-Methane and Carbon Dioxide-Nitrogen Mixtures: Comparison with Thermodynamic Models
Erin L. Roberts and John J. Carroll
Gas Liquids Engineering, Calgary, Alberta, Canada
Abstract
The physical properties of acid-gas injection streams are important for use in design considerations of the acid-gas scheme. One such property is the enthalpy of the stream. As carbon dioxide is rarely pure, with methane and nitrogen being common impurities in the stream, the effect of these impurities on the enthalpy is also important to consider.
This study compares experimentally determined excess enthalpies and enthalpy departures from literature to the enthalpy predictions of five different models, Benedict-Webb-Rubin, Lee-Kesler, Soave-Redlich-Kwong, and Peng-Robinson from VMGSim, as well as AQUAlibrium software. The mixtures studied are carbon dioxide-methane, as well as carbon dioxide- nitrogen mixtures at a wide range of compositions.
The Soave-Redlich-Kwong model gave the most accurate predictions for both the excess enthalpies and enthalpy departures, with Lee-Kesler frequently giving the least accurate predictions for the mixtures.
1.1 Introduction
An increase in demand of natural gas has led producers to pursue poorer quality reservoirs. These contain higher levels of carbon dioxide that then must be responsibly disposed. Regulations prevent the flaring of the acid-gas mixtures, therefore requiring an alternate means of disposal. One such method is the injection of acid gas into subsurface reservoirs.
An understanding of the physical properties of the stream is essential in the design of the acid-gas injection scheme. The enthalpy of the stream is required in the design of the compressor for injection. Common impurities in the carbon dioxide include methane and nitrogen; therefore the effect of these impurities on the enthalpy of carbon dioxide is required for design.
This paper investigates the accuracy of five different thermodynamic models for predicting such mixtures. Four different equations of state, Benedict-Webb-Rubin (BWR), Lee-Kesler (LK), Soave-Redlich-Kwong (SRK), Peng-Robinson (1978) were used with VMGSim software, as well as the AQUAlibrium model. BWR and LK are multi-constant equations, and SRK and PR78 are cubic equations of state. The AQUAlibrium model uses a variation of Peng-Robinson.
1.2 Enthalpy
The enthalpy of mixtures can be determined in a number of ways. One method is to use excess enthalpy (enthalpy of mixing). Excess enthalpy is defined as
(1.1)
where: HE – Excess enthalpy
Hm – Enthalpy of mixture
Hi – Enthalpy of component i
xi – mol fraction of component i
Alternatively, the enthalpy of the mixture can be represented as an enthalpy departure, a difference between the enthalpy at a given pressure, and the enthalpy at a reference pressure while keeping the temperature constant.
Enthalpies can be expressed in J/mol, or for greater relevance to acid-gas injection design, can be expressed in HP/MMSCFD. The conversion between units is 1 HP/MMSCFD to 53.86 J/mol.
1.3 Literature Review
A review of literature was performed to compile experimental data for the enthalpy of carbon dioxide-methane mixtures as well as carbon dioxide-nitrogen mixtures. Table 1.1 summarizes the relevant data used in this study.
Table 1.1 Summary of experimental data of enthalpy of carbon dioxide mixtures.
Temperature (°C)
Impurity
Comments
10–80
Methane
Excess enthalpies
All vapour enthalpies
646 data points
20, 32, 40
Methane
Excess enthalpies
All vapour enthalpies
60 data points
0–90
Methane
Enthalpy departure
Liquid and vapour densities
42 data points
–46–149
Methane
Enthalpy departure
Liquid and vapour densities
46 data points
40
Nitrogen
Excess enthalpies
All vapour enthalpies
108 data points
31, 40
Nitrogen
Excess enthalpies
All vapour enthalpies
27 data points
1. Lee & Mather (1972)
2. Barry et al. (1982)
3. Ng & Mather (1976)
4. Peterson & Wilson (1974)
5. Lee & Mather (1970)
6. Hejmadi et al. (1971)
1.3.1 Carbon Dioxide-Methane
The most extensive study performed for enthalpies of carbon dioxide-methane mixtures was performed by Lee & Mather (1972). Their study consisted of mol fractions of 0.1–0.9, taken at intervals of 0.1, for a total of 9 different mol fractions. Measurements of excess enthalpy were reported at 8 different temperatures from 10–80 °C, with ranges of pressure of 1.0–4.4 MPa for 10 °C, 1.0- 5.07 for 20 °C, 1.0–11.1 for 40 °C, and 1.0–10.1 for 32 °C, 50 °C, 60 °C, 70 °C, and 80 °C. In total, 648 data points were reported. Two typographical errors were found in the data set; they are not included in the numerical error analysis but are represented in the figures.
Another smaller study was performed by Barry et al. (1982), for excess enthalpies of carbon dioxide-methane mixtures. Data was taken at three different temperatures, 20 °C, 32 °C, and 40 °C. Seven different pressures were used, ranging from 0.51 MPa to 4.6 MPa, with pressure of over 2 MPa only being measured for 40 °C. The mol fractions measured were not taken in increments, instead were taken at a wide variety of fractions ranging from 0.1 to 0.9.
Two other studies were done using enthalpy departures by Ng & Mather (1976) and Peterson & Wilson (1974). Ng & Mather (1976) used pressures of 3–13.7 MPa, and temperatures of 0–90 °C for mol fractions of 0.145 and 0.423. They used the ideal gas enthalpy as a reference point to measure the enthalpy departure. Peterson & Wilson (1974) only measured equimolar mixtures of carbon dioxide and methane with pressures from 0.7–13.8 MPa and temperatures of 255.4 K–422 K. The reference enthalpy used was measured at a pressure of 0.138 MPa. These two studies were the only ones that measured both liquid and vapor enthalpies, instead of just vapor.
1.3.2 Carbon Dioxide-Nitrogen
Lee & Mather (1970) and Hejmadi et al. (1971) studied the excess enthalpies of carbon dioxide-nitrogen mixtures. Lee & Mather (1970) looked at mole fractions from 0.1–0.9 at intervals of 0.1. Pressures from 1.01 MPa to 12.16 MPa were used, at only a single temperature of 40 °C.
Hejmadi et al. (1971) used only two different temperatures of 31 °C and 40 °C, and two different pressures of 3.5 MPa and 6.5 MPa. They used mole fraction of nitrogen from 0.2–0.7.
1.4 Calculations
The experimental enthalpies were compared to calculated enthalpies using BWR, LK, SRK, and PR78 thermodynamic models from VMGSim software, as well as using AQUAlibrium software.
The six different mixtures (four with methane, two with nitrogen) as summarized in Table 1.1 were evaluated. Four error functions for both the excess enthalpies and the enthalpy departures were used to analyze the accuracy of the prediction of each method.
For the excess enthalpies, the absolute average difference (AAD) was defined as;
(1.2)
where: NP – number of points
HEexp – experimental excess enthalpy
HEcalc – calculated excess enthalpy
and the average difference (AD) was defined as:
(1.3)
The absolute average error (AAE) in excess enthalpies was defined as:
(1.4)
and the average error (AE) was defined as:
(1.5)
For enthalpy departures, the absolute average difference
(1.6)
where H° – enthalpy of mixture at reference pressure
H – enthalpy of mixture at measured pressure
and the average difference was defined as:
(1.7)
The absolute average error for enthalpy departure was defined as:
(1.8)
and the average error was defined as:
(1.9)
1.4.1 Benedict-Webb-Rubin
For the Lee & Mather (1972) methane data of excess enthalpies, the AAD was 78.1 J/mol and the AD was 2.6 J/mol. The AAE was 19.0% and the AE was –14.6%. The maximum difference was 2113.2 J/mol occurring at 8.11 MPa and a mole fraction of 0.2. The maximum error was 131.7% at the same conditions as the maximum difference. At lower pressures, the enthalpies were overestimated, and at the higher pressures they were underestimated. The greatest deviations occurred when there was a rapid change in enthalpy with pressure. This occurred at around 7–10 MPa for the 32 °C and 40 °C temperatures. There was also a very large difference between the calculated and experimental enthalpy for the 10.13 MPa isobar at 50 °C. Figures 1.1 through 1.8 show the experimental and calculated enthalpies for the different temperatures.
Figure 1.1 Experimental and calculated enthalpies at 10 °C using BWR (Lee & Mather, 1972).
Figure 1.2 Experimental and calculated enthalpies at 20 °C using BWR (Lee & Mather, 1972).
Figure 1.3 Experimental and calculated enthalpies at 32 °C using BWR (Lee & Mather, 1972).
Figure 1.4 Experimental and calculated enthalpies at 40 °C using BWR (Lee & Mather, 1972).
