Carbon Dioxide Sequestration and Related Technologies

Ying Wu, John J. Carroll, Zhimin Du, John J. Carroll, Ying Wu, Zhimin Du, John J. Carroll, Ying Wu, Zhimin Du

• Publisher: Wiley-Scrivener
• Year: 2011
• Print ISBN: 9780470938768
• eBook ISBN: 9781118175538
• Edition: 1
• Topic: Technology & Engineering
• Subtopic: Fossil Fuels
• Index: Technology & Engineering

Carbon dioxide sequestration is a technology that is being explored to curb the anthropogenic emission of CO2 into the atmosphere. Carbon dioxide has been implicated in the global climate change and reducing them is a potential solution.

The injection of carbon dioxide for enhanced oil recovery (EOR) has the duel benefit of sequestering the CO2 and extending the life of some older fields. Sequestering CO2 and EOR have many shared elements that make them comparable.

This volume presents some of the latest information on these processes covering physical properties, operations, design, reservoir engineering, and geochemistry for AGI and the related technologies.

SECTION 1

DATA AND CORRELATION

Chapter 1

Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds

Ray. A. Tomcej

Tomcej Engineering Inc. Edmonton, AB, Canada

Abstract

Aromatic hydrocarbons which are present in sour natural gas streams can be absorbed into the amine treating solution at the bottom of the contactor and exit in the rich amine stream. Depending on the process configuration, these dissolved hydrocarbons can end up in the acid gas leaving the amine regenerator. In acid gas injection facilities, trace amounts of heavy hydrocarbons in the acid gas may lead to the formation of a sour hydrocarbon liquid phase in the compressor interstage scrubbers.

In this exploratory work, a cubic equation-of-state (EOS) model was used to make predictions of non-aqueous (L1) dew points in acid gas systems. The objective was to develop a better understanding of the conditions under which this phenomenon can occur, and to reinforce the need for accurate experimental vapor-liquid equilibrium data to support cost effective design and model development.

1.1 Introduction

Benzene, toluene, ethyl benzene and xylene isomers are commonly referred to collectively as BTEX compounds. These compounds are known to be toxic to humans and their containment and disposal are of special interest to the hydrocarbon industry. BTEX environmental contamination is often linked to leakage from underground gasoline storage tanks or accidental spills. Awareness of this toxicity led to regulated clean air emission standards that directly impact the natural gas processing industry as trace amounts of BTEX compounds are associated with produced fluids such as natural gas.

Sour gas production generally involves a subsequent processing step in which the hydrogen sulphide (H2S) and carbon dioxide (CO2) are removed to produce an acid gas stream that may be a candidate for acid gas injection. Liquid solvents that are used to remove the H2S and CO2 from the gas stream are often aqueous solutions of organic chemicals that have a high affinity for the BTEX compounds.

Distribution of the BTEX compounds within the various streams of a natural gas processing plant is a complex phenomenon involving many interrelated process variables such as operating pressures and temperatures, amine composition, amine circulation rates, and others. Of particular interest in acid gas injection, is the amount of BTEX compounds that end up in the acid gas product leaving the amine regenerator.

The presence of trace quantities of BTEX compounds in the acid gas, if unaccounted for at the design stage, may lead to the unexpected formation of a sour non-aqueous liquid phase in the compressor train, and considerable operational difficulties. The objective of this work was to develop a better understanding of the conditions under which this phenomenon can occur, and to reinforce the need for accurate experimental vapor-liquid equilibrium data to support cost effective design and model development.

1.2 Previous Studies

In order to estimate the levels of BTEX compounds that will be present in the acid gas, there is a need for accurate vapor-liquid equilibria (VLE) and/or vapor-liquid-liquid equilibria (VLLE) data for BTEX and similar hydrocarbons in amine treating solutions under rich amine conditions. Operating plant data are also useful to verify the predictions of any thermodynamic model.

Ng et al. (1999) provided an overview of specific phase equilibria data and physical properties that are required for reliable design of acid gas injection facilities. Hegarty and Hawthorne (1999) presented valuable operating data for a Canadian gas plant using MDEA in which measured BTEX compositions were reported. McIntyre et al. (2001) and Bullin and Brown (2004) tabulated the experimental data available for hydrocarbon and BTEX solubility in amine treating solutions and demonstrated general trends in amine plant BTEX absorption using computer simulation. Valtz et al. (2002) presented a comprehensive set of fundamental solubility data for aromatic hydrocarbons in aqueous amine solutions. Miller and Hawthorne (2000) and Jou and Mather (2003) measured the solubility of BTEX compounds in water.

Clark et al. (2002) measured bubble and dew points for a nominal 10 mol% H2S/90 mol% CO2 mixture and regressed an equation of state to match the phase envelope. Satyro and van der Lee (2009) demonstrated that with suitable modification to interaction parameters, a cubic equation of state can provide reliable predictions of phase behavior in sour gas mixtures.

1.3 Thermodynamic Model

A rigorous treatment of the complex phase behavior in the H2S-CO2-water-BTEX system was beyond the scope of this work, which was intended to be exploratory in nature. The Peng-Robinson equation-of-state with classical van der Waals mixing rules was used in this study. The interaction parameter for the H2S-CO2 binary was set to 0.1 and all others were set to zero. Table 1 co...

Table of contents

• Cover
• Half Title page
• Title page
• Copyright page
• Introduction
• Section 1: Data and Correlation
• Section 2: Process Engineering
• Section 3: Reservoir Engineering
• Section 4: Enhanced Oil Recovery (EOR)
• Section 5: Geology and Geochemistry
• Section 6: Well Technology
• Section 7: Corrosion
• Index
• Also of Interest