This document provides an overview of key concepts for performing phase equilibrium calculations on reservoir fluids, including:
1) Cubic equations of state and properties required for components in mixtures like critical temperature, pressure, and acentric factor.
2) Calculating these properties for hydrocarbon components and lumping heavier fractions into pseudocomponents.
3) Using equations of state to relate fugacity coefficients to vapor-liquid equilibrium and calculate K-factors for flash calculations.
This document provides an overview of reservoir fluid properties and flash calculations. It covers topics such as cubic equations of state used to model real gases, non-cubic equations of state, equations of state for mixtures, and modeling hydrocarbons. The document then focuses on flash calculations, which are used to determine the composition and amounts of hydrocarbon liquid and gas that coexist at reservoir conditions. It discusses PT flash processes, equilibrium ratios, calculating mixture saturation points, and using equations of state to model phase behavior.
This document provides an overview of a course on reservoir fluid properties. The course covers:
1. Reservoir fluid behaviors and properties of petroleum reservoirs including oil and gas.
2. Introduction to physical properties of gases including gas behavior, properties such as compressibility factor and how they are calculated for pure components and mixtures.
3. Behavior of ideal gases and real gases, definitions of compressibility factor, and use of the corresponding states principle and mixing rules to determine properties of gas mixtures.
This document discusses compositional analysis of reservoir fluid samples. It describes how bottom hole and separator samples are taken and analyzed in the lab using gas chromatography and true boiling point distillation. Quality control checks are important to ensure samples are representative, such as verifying bottom hole samples are single-phase and separator oil and gas phase envelopes intersect at separator conditions. The ratio of component mole fractions in separator phases, known as the K-factor, is also used for quality control.
This document provides an overview of equations of state (EoS) models for characterizing reservoir fluids. It discusses several commonly used cubic EoS models including the van der Waals, Redlich-Kwong, Soave-Redlich-Kwong (SRK), and Peng-Robinson (PR) equations. It also covers the application of EoS models to mixtures and the characterization of C7+ hydrocarbon components in petroleum fluids. The document is intended as training material for understanding advanced EoS and modeling complex reservoir fluids.
This document provides an overview of equations of state and the compressibility factor. It discusses the ideal gas law and deviations from it, using the compressibility factor Z to quantify these deviations. Various equations of state are presented, including the van der Waals and virial equations. Cubic equations of state are discussed in depth, along with their history and widespread use in the petroleum industry. The challenges of modeling fluid properties in the critical region and at high pressures are also addressed.
This document provides an overview of reservoir fluid properties and phase behavior. It discusses that reservoir fluids are mixtures of hydrocarbons and other components like water and gases. It explains the molecular structures of hydrocarbon components and defines terms like C1, C7+. The document covers phase behavior of single-component and multi-component systems using pressure-volume and pressure-temperature diagrams. It illustrates concepts of vapor pressure curves, critical points, and phase envelopes which define the different states that reservoir fluids can exist in based on temperature and pressure conditions.
This document provides an overview of reservoir fluid properties including:
1. Crude oil properties such as density, gas solubility, bubble point pressure, formation volume factor, compressibility, and correlations to calculate these properties.
2. Water properties including water formation volume factor, viscosity, gas solubility in water, and water isothermal compressibility.
3. The total formation volume factor and viscosity of crude oil are also discussed along with definitions of dead-oil, saturated-oil, and undersaturated oil viscosities.
This document covers reservoir engineering concepts related to properties of gas, oil, and water in reservoirs. It discusses key properties like gas compressibility, oil viscosity and density. It explains how to calculate properties of dead oil, saturated oil and undersaturated oil using various correlations. Laboratory analysis and experiments for determining fluid properties are also summarized, including different types of tests. The document provides methods to estimate properties like oil and water viscosity, gas solubility in water, and water compressibility.
This document provides an overview of reservoir fluid properties and flash calculations. It covers topics such as cubic equations of state used to model real gases, non-cubic equations of state, equations of state for mixtures, and modeling hydrocarbons. The document then focuses on flash calculations, which are used to determine the composition and amounts of hydrocarbon liquid and gas that coexist at reservoir conditions. It discusses PT flash processes, equilibrium ratios, calculating mixture saturation points, and using equations of state to model phase behavior.
This document provides an overview of a course on reservoir fluid properties. The course covers:
1. Reservoir fluid behaviors and properties of petroleum reservoirs including oil and gas.
2. Introduction to physical properties of gases including gas behavior, properties such as compressibility factor and how they are calculated for pure components and mixtures.
3. Behavior of ideal gases and real gases, definitions of compressibility factor, and use of the corresponding states principle and mixing rules to determine properties of gas mixtures.
This document discusses compositional analysis of reservoir fluid samples. It describes how bottom hole and separator samples are taken and analyzed in the lab using gas chromatography and true boiling point distillation. Quality control checks are important to ensure samples are representative, such as verifying bottom hole samples are single-phase and separator oil and gas phase envelopes intersect at separator conditions. The ratio of component mole fractions in separator phases, known as the K-factor, is also used for quality control.
This document provides an overview of equations of state (EoS) models for characterizing reservoir fluids. It discusses several commonly used cubic EoS models including the van der Waals, Redlich-Kwong, Soave-Redlich-Kwong (SRK), and Peng-Robinson (PR) equations. It also covers the application of EoS models to mixtures and the characterization of C7+ hydrocarbon components in petroleum fluids. The document is intended as training material for understanding advanced EoS and modeling complex reservoir fluids.
This document provides an overview of equations of state and the compressibility factor. It discusses the ideal gas law and deviations from it, using the compressibility factor Z to quantify these deviations. Various equations of state are presented, including the van der Waals and virial equations. Cubic equations of state are discussed in depth, along with their history and widespread use in the petroleum industry. The challenges of modeling fluid properties in the critical region and at high pressures are also addressed.
This document provides an overview of reservoir fluid properties and phase behavior. It discusses that reservoir fluids are mixtures of hydrocarbons and other components like water and gases. It explains the molecular structures of hydrocarbon components and defines terms like C1, C7+. The document covers phase behavior of single-component and multi-component systems using pressure-volume and pressure-temperature diagrams. It illustrates concepts of vapor pressure curves, critical points, and phase envelopes which define the different states that reservoir fluids can exist in based on temperature and pressure conditions.
This document provides an overview of reservoir fluid properties including:
1. Crude oil properties such as density, gas solubility, bubble point pressure, formation volume factor, compressibility, and correlations to calculate these properties.
2. Water properties including water formation volume factor, viscosity, gas solubility in water, and water isothermal compressibility.
3. The total formation volume factor and viscosity of crude oil are also discussed along with definitions of dead-oil, saturated-oil, and undersaturated oil viscosities.
This document covers reservoir engineering concepts related to properties of gas, oil, and water in reservoirs. It discusses key properties like gas compressibility, oil viscosity and density. It explains how to calculate properties of dead oil, saturated oil and undersaturated oil using various correlations. Laboratory analysis and experiments for determining fluid properties are also summarized, including different types of tests. The document provides methods to estimate properties like oil and water viscosity, gas solubility in water, and water compressibility.
This document provides an overview of key concepts in reservoir fluid properties including:
- Formation volume factors (Bo and Bt) which relate the volume of oil and gas in the reservoir to stock tank conditions.
- Methods for determining PVT properties like gas solubility and Bo/Bt through laboratory experiments as pressure changes.
- Key fluid properties like bubble point pressure, compressibility, and molecular weight that impact reservoir performance.
- Techniques for estimating fluid properties using correlations with parameters like boiling point and API gravity.
The document discusses laboratory analysis techniques for gas condensate systems, including recombination and analysis of separator samples, constant-composition expansion tests, and constant-volume depletion tests. It describes the procedures for these various laboratory experiments in detail, including determining fluid properties like compressibility factors and calculating quantities like retrograde liquid saturation and cumulative gas production. The goal is to better understand the pressure-volume-temperature behavior and compositional changes that occur during depletion of a gas condensate reservoir.
The document provides an overview of a course on reservoir fluid properties. It discusses different types of hydrocarbon reservoirs including oil reservoirs which can be undersaturated, saturated, or gas-capped. Gas reservoirs include retrograde gas-condensate reservoirs where pressure reduction causes condensation, wet gas reservoirs which produce liquid at surface, and dry gas reservoirs which only produce gas. Pressure-temperature diagrams are used to classify reservoirs and illustrate phase behavior of reservoir fluids.
This document provides an overview of a reservoir fluid properties course covering reservoir hydrocarbons including natural gas and crude oil. The course discusses sampling and analysis of reservoir fluids, properties of natural gases such as density and compressibility, properties of crude oils like density and gas solubility, and how reservoir fluids change from reservoir conditions to downstream production and processing facilities as pressure and temperature decrease. Key concepts covered include gas formation volume factor, gas expansion factor, gas solubility and its relationship to pressure and temperature, and methods for determining fluid properties.
This document provides an overview of reservoir fluid properties, including crude oil, water, and gas properties. It discusses key properties such as formation volume factors, viscosity, surface tension, and gas solubility. It summarizes various empirical correlations used to estimate these properties based on temperature, pressure, oil composition and other factors. The document is from a course on reservoir fluid properties and focuses on definitions and methods for calculating important PVT properties.
This document provides an overview of reservoir fluid properties and natural gas behavior. It discusses:
1. The importance of understanding reservoir fluid properties to predict volumetric behavior as a function of pressure. These properties are determined experimentally or through correlations.
2. Natural gas is a mixture of hydrocarbon and non-hydrocarbon gases. The properties of gas mixtures can be determined using appropriate mixing rules for the individual components.
3. Deviations from ideal gas behavior increase with pressure and temperature and gas composition. Equations of state and compressibility factors are used to more accurately model real gas behavior.
The document provides an overview of a course on reservoir fluid properties. It discusses different types of hydrocarbon reservoirs and how they are classified. It describes the phase behavior of hydrocarbon mixtures using pressure-temperature diagrams. Key points on these diagrams are defined, including the bubble point curve, dew point curve, and critical point. Based on the position of the initial reservoir pressure and temperature on the diagram, reservoirs can be classified as oil or gas reservoirs. Oil reservoirs are further divided into undersaturated, saturated, and gas-cap categories. Common types of crude oils like ordinary black oil, low-shrinkage oil, and volatile oil are also described. Gas reservoirs include retrograde gas-condensate, near-critical gas-condens
Q913 rfp w3 lec 12, Separators and Phase envelope calculationsAFATous
This document outlines course material on reservoir fluid properties, separators, and phase envelope calculations. It covers topics such as PT flash processes, mixture saturation points, phase envelope determination using Michelsen's technique, and separator calculations to optimize pressure and determine stock tank oil properties. Examples of phase envelopes are shown for oil and gas condensate mixtures, illustrating properties like critical points. The document provides information to understand fluid behavior relevant to production operations.
This document provides an overview of key reservoir fluid properties including methods for calculating z-factors, gas properties such as compressibility and viscosity, crude oil properties like density and solution gas, and empirical correlations for determining properties like gas solubility, bubble point pressure, and formation volume factors. The document discusses various correlations for estimating properties in the absence of laboratory measurements and defines important concepts such as gas solubility, solution gas, and bubble point pressure.
This document describes procedures for analyzing reservoir fluid properties in the laboratory, including crude oil properties, water properties, and various laboratory tests. It discusses measuring the total formation volume factor, viscosity, surface tension, and other properties of crude oil and water. It also describes primary tests conducted on-site, routine laboratory tests like compositional analysis and constant-composition expansion, and special laboratory PVT tests. The constant-composition expansion test measures saturation pressure and compressibility by reducing pressure in a cell and measuring volume changes. The results are used to calculate fluid densities and compressibility coefficients above the saturation pressure.
The document provides an overview of a course on reservoir fluid properties. It covers the following topics:
1. An introduction to petroleum engineering and the importance of understanding reservoir fluids.
2. The formation and extraction of petroleum, including drilling and production.
3. The constituents of reservoir fluids including hydrocarbon components like methane, paraffins, naphthenes and aromatics. It also discusses non-hydrocarbon components like water, nitrogen and carbon dioxide.
4. The phase behavior of pure components and mixtures, including phase envelopes and using pressure-temperature and pressure-volume diagrams to illustrate behavior.
The document discusses procedures and results from differential liberation experiments used to characterize reservoir fluids. Key points:
- Differential liberation experiments slowly depressurize a reservoir fluid sample to measure properties like oil and gas volumes, gas composition, and solution gas-oil ratio at different pressures.
- Properties measured include formation volumes factors (Bo and Bg) which indicate volume changes from reservoir to surface conditions, and solution gas-oil ratio (Rs) which provides ratio of gas to oil volumes.
- Trends in Bo, Bg and Rs with pressure provide insight into fluid behavior during production.
This document provides an overview of three primary reservoir fluid property experiments: constant-mass expansion (CME), constant-volume depletion (CVD), and differential liberation (DL). It describes the objectives, procedures, and key results of each experiment. The CME experiment measures formation volume factor, compressibility, and relative fluid volumes at varying pressures. The CVD simulates reservoir depletion, measuring properties like liquid dropout and gas compositions. The DL characterizes differential gas liberation from oil during pressure decline.
This document summarizes key topics in reservoir engineering related to gas well performance and driving mechanisms. It covers turbulent gas flow models including the laminar-inertial-turbulent approach and pseudopressure method. It also discusses calculating inflow performance relationships, predicting future IPRs, modeling horizontal gas wells, and the primary recovery mechanisms of depletion drive, gas cap drive, water drive, and combination drive.
This document provides an overview of reservoir engineering 1 course material covering reservoir fluids and gas properties. It discusses:
1. Classification of oil and gas reservoirs based on pressure-temperature diagrams and fluid compositions. Reservoir fluids can exist as gas, liquid, solid, or combinations and behave differently based on reservoir conditions.
2. Key gas properties like compressibility factor, density, viscosity that are important for reservoir calculations. Real gases deviate from ideal gas behavior more at high pressures.
3. Methods for determining gas properties including compressibility factor charts and equations of state that account for non-ideal behaviors and non-hydrocarbon gas components.
This document provides an overview of methods for calculating key reservoir fluid properties including: oil formation volume factor (Bo), gas solubility (Rs), bubble point pressure (Pb), oil density, and oil compressibility (Co). It describes several commonly used correlations for determining these properties as functions of temperature, pressure, gas and oil specific gravities. The correlations compared include those developed by Standing, Vasquez-Beggs, Glaso, Marhoun, and Petrosky-Farshad. The document also addresses calculating fluid properties for both undersaturated and saturated oil conditions.
This document provides an overview of methods for calculating key gas properties including:
1. The z-factor, which can be calculated using correlations like Hall-Yarborough or Dranchuk-Abu-Kassem that were developed based on the Standing-Katz chart.
2. Isothermal gas compressibility (Cg), which can be determined from the z-factor or using models that relate it to reduced gas density.
3. Gas formation volume factor (Bg) and gas expansion factor (Eg), which relate the volume of gas at reservoir conditions to standard conditions.
4. Gas viscosity, which can be estimated using correlations like Carr-Kobayashi-Burrows that are functions of
This document provides an overview of methods for calculating reservoir fluid properties, including crude oil and water properties. It discusses calculating the total formation volume factor (Bt) using correlations like Standing's and Glaso's. It also covers calculating crude oil viscosity, including dead-oil viscosity using Beal's correlation, saturated oil viscosity using Chew-Connally, and undersaturated oil viscosity using Vasquez-Beggs. The document provides equations and discusses experimental data ranges for various fluid property correlations.
This document outlines topics covered in a reservoir engineering course, including reservoir fluid behaviors, properties of petroleum reservoirs, gas behavior, and properties of crude oil systems. It specifically discusses properties of interest like density, solution gas, bubble point pressure, formation volume factor, viscosity and more. It provides empirical correlations to estimate properties like gas solubility, bubble point pressure, and formation volume factor as a function of parameters like solubility, gas gravity, oil gravity and temperature. The document is focused on understanding physical properties of crude oil and gas reservoirs which is important for reservoir engineering applications and problem solving.
This document provides an overview of methods for calculating properties of reservoir fluids including gas and crude oil. It discusses empirical correlations for calculating z-factors, gas properties like compressibility and viscosity, and crude oil properties like density, solubility of dissolved gas, and bubble point pressure. The key empirical correlations presented for estimating gas solubility (Rs) and methods for determining bubble point pressure are Standing, Vasquez-Beggs, Glaso, Marhoun, Petrosky-Farshad, and correlations based on experimental PVT data.
This document provides an overview of a chemical engineering course on thermodynamics 2. The course covers topics such as thermodynamic properties of fluid mixtures, phase equilibria, solution thermodynamics, and chemical reaction equilibria. It lists recommended reference books and the grading breakdown. Key concepts that will be discussed include thermodynamic properties of fluids mixtures, Maxwell equations, residual properties, Gibbs energy as a generating function, phase equilibrium criteria for vapor-liquid systems, and the Clapeyron equation. Assignments and exams make up 10% and 90% of the final grade respectively.
This document provides an overview of properties of pure substances and phase change processes. It introduces key concepts such as pure substances, phases of matter, phase change diagrams, property tables, and the ideal gas law. Specific topics covered include saturated liquids and vapors, phase change temperatures and pressures, property diagrams, determining properties from tables, and using the ideal gas equation of state to model real gases. The document uses water as an example pure substance to illustrate these concepts through diagrams and examples.
This document provides an overview of key concepts in reservoir fluid properties including:
- Formation volume factors (Bo and Bt) which relate the volume of oil and gas in the reservoir to stock tank conditions.
- Methods for determining PVT properties like gas solubility and Bo/Bt through laboratory experiments as pressure changes.
- Key fluid properties like bubble point pressure, compressibility, and molecular weight that impact reservoir performance.
- Techniques for estimating fluid properties using correlations with parameters like boiling point and API gravity.
The document discusses laboratory analysis techniques for gas condensate systems, including recombination and analysis of separator samples, constant-composition expansion tests, and constant-volume depletion tests. It describes the procedures for these various laboratory experiments in detail, including determining fluid properties like compressibility factors and calculating quantities like retrograde liquid saturation and cumulative gas production. The goal is to better understand the pressure-volume-temperature behavior and compositional changes that occur during depletion of a gas condensate reservoir.
The document provides an overview of a course on reservoir fluid properties. It discusses different types of hydrocarbon reservoirs including oil reservoirs which can be undersaturated, saturated, or gas-capped. Gas reservoirs include retrograde gas-condensate reservoirs where pressure reduction causes condensation, wet gas reservoirs which produce liquid at surface, and dry gas reservoirs which only produce gas. Pressure-temperature diagrams are used to classify reservoirs and illustrate phase behavior of reservoir fluids.
This document provides an overview of a reservoir fluid properties course covering reservoir hydrocarbons including natural gas and crude oil. The course discusses sampling and analysis of reservoir fluids, properties of natural gases such as density and compressibility, properties of crude oils like density and gas solubility, and how reservoir fluids change from reservoir conditions to downstream production and processing facilities as pressure and temperature decrease. Key concepts covered include gas formation volume factor, gas expansion factor, gas solubility and its relationship to pressure and temperature, and methods for determining fluid properties.
This document provides an overview of reservoir fluid properties, including crude oil, water, and gas properties. It discusses key properties such as formation volume factors, viscosity, surface tension, and gas solubility. It summarizes various empirical correlations used to estimate these properties based on temperature, pressure, oil composition and other factors. The document is from a course on reservoir fluid properties and focuses on definitions and methods for calculating important PVT properties.
This document provides an overview of reservoir fluid properties and natural gas behavior. It discusses:
1. The importance of understanding reservoir fluid properties to predict volumetric behavior as a function of pressure. These properties are determined experimentally or through correlations.
2. Natural gas is a mixture of hydrocarbon and non-hydrocarbon gases. The properties of gas mixtures can be determined using appropriate mixing rules for the individual components.
3. Deviations from ideal gas behavior increase with pressure and temperature and gas composition. Equations of state and compressibility factors are used to more accurately model real gas behavior.
The document provides an overview of a course on reservoir fluid properties. It discusses different types of hydrocarbon reservoirs and how they are classified. It describes the phase behavior of hydrocarbon mixtures using pressure-temperature diagrams. Key points on these diagrams are defined, including the bubble point curve, dew point curve, and critical point. Based on the position of the initial reservoir pressure and temperature on the diagram, reservoirs can be classified as oil or gas reservoirs. Oil reservoirs are further divided into undersaturated, saturated, and gas-cap categories. Common types of crude oils like ordinary black oil, low-shrinkage oil, and volatile oil are also described. Gas reservoirs include retrograde gas-condensate, near-critical gas-condens
Q913 rfp w3 lec 12, Separators and Phase envelope calculationsAFATous
This document outlines course material on reservoir fluid properties, separators, and phase envelope calculations. It covers topics such as PT flash processes, mixture saturation points, phase envelope determination using Michelsen's technique, and separator calculations to optimize pressure and determine stock tank oil properties. Examples of phase envelopes are shown for oil and gas condensate mixtures, illustrating properties like critical points. The document provides information to understand fluid behavior relevant to production operations.
This document provides an overview of key reservoir fluid properties including methods for calculating z-factors, gas properties such as compressibility and viscosity, crude oil properties like density and solution gas, and empirical correlations for determining properties like gas solubility, bubble point pressure, and formation volume factors. The document discusses various correlations for estimating properties in the absence of laboratory measurements and defines important concepts such as gas solubility, solution gas, and bubble point pressure.
This document describes procedures for analyzing reservoir fluid properties in the laboratory, including crude oil properties, water properties, and various laboratory tests. It discusses measuring the total formation volume factor, viscosity, surface tension, and other properties of crude oil and water. It also describes primary tests conducted on-site, routine laboratory tests like compositional analysis and constant-composition expansion, and special laboratory PVT tests. The constant-composition expansion test measures saturation pressure and compressibility by reducing pressure in a cell and measuring volume changes. The results are used to calculate fluid densities and compressibility coefficients above the saturation pressure.
The document provides an overview of a course on reservoir fluid properties. It covers the following topics:
1. An introduction to petroleum engineering and the importance of understanding reservoir fluids.
2. The formation and extraction of petroleum, including drilling and production.
3. The constituents of reservoir fluids including hydrocarbon components like methane, paraffins, naphthenes and aromatics. It also discusses non-hydrocarbon components like water, nitrogen and carbon dioxide.
4. The phase behavior of pure components and mixtures, including phase envelopes and using pressure-temperature and pressure-volume diagrams to illustrate behavior.
The document discusses procedures and results from differential liberation experiments used to characterize reservoir fluids. Key points:
- Differential liberation experiments slowly depressurize a reservoir fluid sample to measure properties like oil and gas volumes, gas composition, and solution gas-oil ratio at different pressures.
- Properties measured include formation volumes factors (Bo and Bg) which indicate volume changes from reservoir to surface conditions, and solution gas-oil ratio (Rs) which provides ratio of gas to oil volumes.
- Trends in Bo, Bg and Rs with pressure provide insight into fluid behavior during production.
This document provides an overview of three primary reservoir fluid property experiments: constant-mass expansion (CME), constant-volume depletion (CVD), and differential liberation (DL). It describes the objectives, procedures, and key results of each experiment. The CME experiment measures formation volume factor, compressibility, and relative fluid volumes at varying pressures. The CVD simulates reservoir depletion, measuring properties like liquid dropout and gas compositions. The DL characterizes differential gas liberation from oil during pressure decline.
This document summarizes key topics in reservoir engineering related to gas well performance and driving mechanisms. It covers turbulent gas flow models including the laminar-inertial-turbulent approach and pseudopressure method. It also discusses calculating inflow performance relationships, predicting future IPRs, modeling horizontal gas wells, and the primary recovery mechanisms of depletion drive, gas cap drive, water drive, and combination drive.
This document provides an overview of reservoir engineering 1 course material covering reservoir fluids and gas properties. It discusses:
1. Classification of oil and gas reservoirs based on pressure-temperature diagrams and fluid compositions. Reservoir fluids can exist as gas, liquid, solid, or combinations and behave differently based on reservoir conditions.
2. Key gas properties like compressibility factor, density, viscosity that are important for reservoir calculations. Real gases deviate from ideal gas behavior more at high pressures.
3. Methods for determining gas properties including compressibility factor charts and equations of state that account for non-ideal behaviors and non-hydrocarbon gas components.
This document provides an overview of methods for calculating key reservoir fluid properties including: oil formation volume factor (Bo), gas solubility (Rs), bubble point pressure (Pb), oil density, and oil compressibility (Co). It describes several commonly used correlations for determining these properties as functions of temperature, pressure, gas and oil specific gravities. The correlations compared include those developed by Standing, Vasquez-Beggs, Glaso, Marhoun, and Petrosky-Farshad. The document also addresses calculating fluid properties for both undersaturated and saturated oil conditions.
This document provides an overview of methods for calculating key gas properties including:
1. The z-factor, which can be calculated using correlations like Hall-Yarborough or Dranchuk-Abu-Kassem that were developed based on the Standing-Katz chart.
2. Isothermal gas compressibility (Cg), which can be determined from the z-factor or using models that relate it to reduced gas density.
3. Gas formation volume factor (Bg) and gas expansion factor (Eg), which relate the volume of gas at reservoir conditions to standard conditions.
4. Gas viscosity, which can be estimated using correlations like Carr-Kobayashi-Burrows that are functions of
This document provides an overview of methods for calculating reservoir fluid properties, including crude oil and water properties. It discusses calculating the total formation volume factor (Bt) using correlations like Standing's and Glaso's. It also covers calculating crude oil viscosity, including dead-oil viscosity using Beal's correlation, saturated oil viscosity using Chew-Connally, and undersaturated oil viscosity using Vasquez-Beggs. The document provides equations and discusses experimental data ranges for various fluid property correlations.
This document outlines topics covered in a reservoir engineering course, including reservoir fluid behaviors, properties of petroleum reservoirs, gas behavior, and properties of crude oil systems. It specifically discusses properties of interest like density, solution gas, bubble point pressure, formation volume factor, viscosity and more. It provides empirical correlations to estimate properties like gas solubility, bubble point pressure, and formation volume factor as a function of parameters like solubility, gas gravity, oil gravity and temperature. The document is focused on understanding physical properties of crude oil and gas reservoirs which is important for reservoir engineering applications and problem solving.
This document provides an overview of methods for calculating properties of reservoir fluids including gas and crude oil. It discusses empirical correlations for calculating z-factors, gas properties like compressibility and viscosity, and crude oil properties like density, solubility of dissolved gas, and bubble point pressure. The key empirical correlations presented for estimating gas solubility (Rs) and methods for determining bubble point pressure are Standing, Vasquez-Beggs, Glaso, Marhoun, Petrosky-Farshad, and correlations based on experimental PVT data.
This document provides an overview of a chemical engineering course on thermodynamics 2. The course covers topics such as thermodynamic properties of fluid mixtures, phase equilibria, solution thermodynamics, and chemical reaction equilibria. It lists recommended reference books and the grading breakdown. Key concepts that will be discussed include thermodynamic properties of fluids mixtures, Maxwell equations, residual properties, Gibbs energy as a generating function, phase equilibrium criteria for vapor-liquid systems, and the Clapeyron equation. Assignments and exams make up 10% and 90% of the final grade respectively.
This document provides an overview of properties of pure substances and phase change processes. It introduces key concepts such as pure substances, phases of matter, phase change diagrams, property tables, and the ideal gas law. Specific topics covered include saturated liquids and vapors, phase change temperatures and pressures, property diagrams, determining properties from tables, and using the ideal gas equation of state to model real gases. The document uses water as an example pure substance to illustrate these concepts through diagrams and examples.
The document discusses properties of pure substances, including their phases of vapor, liquid, and solid and how they relate on a pressure-temperature diagram. It explains concepts like saturation temperature and pressure, triple points, and that the state of a pure substance is determined by two independent properties. Tables of thermodynamic properties are commonly available for many pure substances.
Bab 3 Thermodynamic of Engineering ApproachIbnu Hasan
This document discusses properties of pure substances and phase changes. It introduces concepts like saturated liquid, saturated vapor, and phase diagrams. Properties are presented in tables that show how quantities like enthalpy and temperature vary with pressure and phase for substances like water. The ideal gas law is presented as a simple equation of state to model gas behavior.
Liquid-Vapor Equilibria in Binary SystemsKarnav Rana
1) The document discusses liquid-vapor equilibria in binary systems, specifically measuring the compositions of chloroform and acetone mixtures using refractometry.
2) It introduces concepts like Raoult's law and Henry's law to describe ideal and non-ideal behavior in binary solutions, and how vapor pressure varies with composition.
3) Temperature-composition diagrams are used to visualize ideal and non-ideal behavior, including positive and negative deviations from ideality and the possibility of azeotropes.
Presentation is an overview of NASA Computer program CEA (Chemical Equilibrium with Applications) calculates chemical equilibrium product concentrations from any set of reactants and determines thermodynamic and transport properties for products.
This document introduces ammonia-water based vapor absorption refrigeration systems. It discusses key properties of ammonia-water mixtures including pressure-temperature-concentration and enthalpy-temperature-concentration charts. It explains concepts such as the bubble point and dew point temperatures for ammonia-water mixtures and how they are used to construct equilibrium temperature-concentration curves. Mass and energy balances are also analyzed for basic steady flow processes involving ammonia-water mixtures.
This document introduces ammonia-water vapor absorption refrigeration systems. It discusses how ammonia is the refrigerant and water is the absorbent in these systems. Compared to water-lithium bromide systems, ammonia-water systems can be used for both refrigeration and air conditioning but have a more complex design due to the smaller boiling point difference between ammonia and water. The document then discusses properties of ammonia-water mixtures including composition, vapor pressure, and vapor-liquid equilibrium using pressure-temperature-concentration and enthalpy-temperature-concentration charts. It explains concepts such as bubble point, dew point, and how bubble point and dew point lines are determined for ammonia-water mixtures at different
The document discusses using enthalpy vs composition plots, also known as Ponchon-Savarit plots, to obtain information about separation problems involving energy balances based on enthalpy. It explains that these plots show three phases - solid, liquid, and vapor - with temperature represented by tie lines. Points between saturated lines represent two-phase systems, and azeotropes are indicated by vertical isotherms.
This document discusses thermodynamic principles and properties of pure substances. It begins by stating the objectives of evaluating thermodynamic properties using equations of state, charts, and tables. Key points include:
- Equations of state relate pressure, specific volume, and temperature for gases and liquids. The ideal gas law is derived.
- Thermodynamic properties of pure substances can be determined from tables, charts, and equations that account for intermolecular forces.
- Phase diagrams illustrate relationships between pressure, temperature, and state for various processes.
1) Gibbs phase rule determines the number of intensive properties (F) that can be independently varied for a system with N chemical species and P phases. For a single phase of a pure substance, F=2. For two coexisting phases, F=1. For three coexisting phases, F=0.
2) The lever rule determines the mole fraction of each phase in a binary equilibrium phase diagram. It relates the composition of an alloy to the compositions of its constituent phases.
3) The lever rule equation for the weight percentage of an α phase is: Xα = (c - b) / (a - b), where a, b, c are the weight percentages of an element in
The document discusses four common equations of state:
1. Van der Waals equation of state, which was the first to account for finite molecular volume and attraction between molecules.
2. Beattie-Bridgeman equation of state, which has five experimentally determined constants and is valid for densities below 80% of the critical density.
3. Virial equation of state, which can be derived from statistical mechanics and considers interactions between pairs, triplets, and more molecules through virial coefficients.
4. Benedict-Webb-Rubin equation of state, which is one of the most accurate and can be related to a virial equation by expanding an exponential term into two Taylor terms.
AP Chemistry Chapter 15 Sample ExercisesJane Hamze
The document contains sample exercises for calculating equilibrium constants (K) from initial and equilibrium concentrations. The first exercise provides the concentrations of all species at equilibrium and asks to calculate K. The second exercise gives the initial concentrations and the equilibrium concentration of one species, and asks to calculate K. The third exercise provides initial and equilibrium concentrations and asks to determine K for a reaction at a specific temperature.
This document discusses fundamental concepts in thermodynamics including:
- The Gibbs free energy equation relating changes in Gibbs energy to changes in pressure and temperature.
- Definitions of chemical potential and partial molar properties.
- The criteria for phase equilibrium being that the chemical potential of each species is equal in all phases at a given temperature and pressure.
- Equations relating extensive thermodynamic properties of mixtures to partial molar properties and calculating mixture properties from these.
This document provides an overview of Chapter 3 from a thermodynamics textbook. It discusses volumetric properties of pure fluids. The chapter describes phase change processes and diagrams for pure substances. It also discusses property tables that list internal energy, enthalpy, and entropy values for substances, as these relationships are too complex to express through simple equations. Examples are provided on using property tables to determine pressure, temperature, volume changes, and energy changes during phase change processes like vaporization of water.
This document summarizes key concepts in chemistry including:
1) Equilibrium occurs when forward and reverse reaction rates are equal, and concentrations remain constant. The equilibrium constant K relates concentrations.
2) Kc and Kp describe equilibrium using concentrations or pressures. They are related by Kp = Kc(RT)Δn.
3) Le Chatelier's principle states a system at equilibrium will adjust to counteract stresses like concentration changes.
4) Acid-base equilibria involve proton transfer. Water autoionizes and pH relates to [H+]. Buffers resist pH changes.
Abraham model correlations for ionic liquid solvents computational methodolog...Bihan Jiang
The document describes a computational methodology for updating existing Abraham model ion-specific equation coefficients using new experimental solubility and partition coefficient data for ionic liquid solvents. Specifically, it illustrates updating the coefficients for the trifluoroacetate anion based on 51 data points from three ionic liquid solvents containing that anion. The updated coefficients have significantly smaller standard errors and are able to better predict solubility and partition behavior in the three ionic liquids based on the increased data. The methodology allows coefficients to be refined as new data becomes available without needing to re-regress the entire Abraham model data set.
This document provides an overview of thermodynamic concepts related to pure substances, including:
- Phases of pure substances can exist as solids, liquids, or gases, depending on temperature and pressure. Phase changes between these states occur at characteristic saturation temperatures and pressures.
- Property diagrams like temperature-volume (T-V), pressure-volume (P-V), and pressure-temperature (P-T) diagrams are used to illustrate phase changes and relationships between intensive and extensive properties.
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Chapter 4 Energy Analysis of Closed System.pdfCemerlangStudi1
This chapter discusses energy analysis of closed systems. It examines moving boundary work in reciprocating devices like engines. The first law of thermodynamics states the principle of conservation of energy for closed systems. The chapter develops the general energy balance applied to closed systems and defines specific heats at constant volume and pressure. It relates specific heats to changes in internal energy and enthalpy of ideal gases and incompressible substances. Methods to solve energy balance problems involving heat, work, and closed systems are presented.
This document appears to be lecture slides for a course on well logging in Farsi. It includes sections on topics that will be covered, references for further reading, and what appears to be notes on concepts like mud logging, sonic logs, resistivity logs, cross plots, and other well logging tools and techniques. The slides are attributed to Hossein AlamiNia from Islamic Azad University, Quchan Branch.
This document appears to be lecture notes for a class on stimulating and activating oil wells. It includes:
1. An introduction and information about the instructor.
2. Outlines for lecture topics, including well completion, well interventions, and references.
3. Schedules for class sessions with times allocated for presentations, breaks, and reviewing upcoming topics.
The document provides an overview of the class structure and topics to be covered for stimulating and activating oil wells. It outlines the lecture schedule and allocates time for presentations and reviews within the class sessions.
This document appears to be lecture notes from a geology laboratory class presented by Hossein AlamiNia from the Islamic Azad University of Ghoochan. The notes cover various topics relating to rock properties and characteristics, including rock heterogeneity, different classification systems, and methods for describing and analyzing rocks in a lab. Links are provided to online resources with additional information and sample data.
Securing your Kubernetes cluster_ a step-by-step guide to success !KatiaHIMEUR1
Today, after several years of existence, an extremely active community and an ultra-dynamic ecosystem, Kubernetes has established itself as the de facto standard in container orchestration. Thanks to a wide range of managed services, it has never been so easy to set up a ready-to-use Kubernetes cluster.
However, this ease of use means that the subject of security in Kubernetes is often left for later, or even neglected. This exposes companies to significant risks.
In this talk, I'll show you step-by-step how to secure your Kubernetes cluster for greater peace of mind and reliability.
“An Outlook of the Ongoing and Future Relationship between Blockchain Technologies and Process-aware Information Systems.” Invited talk at the joint workshop on Blockchain for Information Systems (BC4IS) and Blockchain for Trusted Data Sharing (B4TDS), co-located with with the 36th International Conference on Advanced Information Systems Engineering (CAiSE), 3 June 2024, Limassol, Cyprus.
Unlock the Future of Search with MongoDB Atlas_ Vector Search Unleashed.pdfMalak Abu Hammad
Discover how MongoDB Atlas and vector search technology can revolutionize your application's search capabilities. This comprehensive presentation covers:
* What is Vector Search?
* Importance and benefits of vector search
* Practical use cases across various industries
* Step-by-step implementation guide
* Live demos with code snippets
* Enhancing LLM capabilities with vector search
* Best practices and optimization strategies
Perfect for developers, AI enthusiasts, and tech leaders. Learn how to leverage MongoDB Atlas to deliver highly relevant, context-aware search results, transforming your data retrieval process. Stay ahead in tech innovation and maximize the potential of your applications.
#MongoDB #VectorSearch #AI #SemanticSearch #TechInnovation #DataScience #LLM #MachineLearning #SearchTechnology
Maruthi Prithivirajan, Head of ASEAN & IN Solution Architecture, Neo4j
Get an inside look at the latest Neo4j innovations that enable relationship-driven intelligence at scale. Learn more about the newest cloud integrations and product enhancements that make Neo4j an essential choice for developers building apps with interconnected data and generative AI.
Dr. Sean Tan, Head of Data Science, Changi Airport Group
Discover how Changi Airport Group (CAG) leverages graph technologies and generative AI to revolutionize their search capabilities. This session delves into the unique search needs of CAG’s diverse passengers and customers, showcasing how graph data structures enhance the accuracy and relevance of AI-generated search results, mitigating the risk of “hallucinations” and improving the overall customer journey.
GraphSummit Singapore | The Future of Agility: Supercharging Digital Transfor...Neo4j
Leonard Jayamohan, Partner & Generative AI Lead, Deloitte
This keynote will reveal how Deloitte leverages Neo4j’s graph power for groundbreaking digital twin solutions, achieving a staggering 100x performance boost. Discover the essential role knowledge graphs play in successful generative AI implementations. Plus, get an exclusive look at an innovative Neo4j + Generative AI solution Deloitte is developing in-house.
Climate Impact of Software Testing at Nordic Testing DaysKari Kakkonen
My slides at Nordic Testing Days 6.6.2024
Climate impact / sustainability of software testing discussed on the talk. ICT and testing must carry their part of global responsibility to help with the climat warming. We can minimize the carbon footprint but we can also have a carbon handprint, a positive impact on the climate. Quality characteristics can be added with sustainability, and then measured continuously. Test environments can be used less, and in smaller scale and on demand. Test techniques can be used in optimizing or minimizing number of tests. Test automation can be used to speed up testing.
Sudheer Mechineni, Head of Application Frameworks, Standard Chartered Bank
Discover how Standard Chartered Bank harnessed the power of Neo4j to transform complex data access challenges into a dynamic, scalable graph database solution. This keynote will cover their journey from initial adoption to deploying a fully automated, enterprise-grade causal cluster, highlighting key strategies for modelling organisational changes and ensuring robust disaster recovery. Learn how these innovations have not only enhanced Standard Chartered Bank’s data infrastructure but also positioned them as pioneers in the banking sector’s adoption of graph technology.
GraphSummit Singapore | The Art of the Possible with Graph - Q2 2024Neo4j
Neha Bajwa, Vice President of Product Marketing, Neo4j
Join us as we explore breakthrough innovations enabled by interconnected data and AI. Discover firsthand how organizations use relationships in data to uncover contextual insights and solve our most pressing challenges – from optimizing supply chains, detecting fraud, and improving customer experiences to accelerating drug discoveries.
Threats to mobile devices are more prevalent and increasing in scope and complexity. Users of mobile devices desire to take full advantage of the features
available on those devices, but many of the features provide convenience and capability but sacrifice security. This best practices guide outlines steps the users can take to better protect personal devices and information.
UiPath Test Automation using UiPath Test Suite series, part 6DianaGray10
Welcome to UiPath Test Automation using UiPath Test Suite series part 6. In this session, we will cover Test Automation with generative AI and Open AI.
UiPath Test Automation with generative AI and Open AI webinar offers an in-depth exploration of leveraging cutting-edge technologies for test automation within the UiPath platform. Attendees will delve into the integration of generative AI, a test automation solution, with Open AI advanced natural language processing capabilities.
Throughout the session, participants will discover how this synergy empowers testers to automate repetitive tasks, enhance testing accuracy, and expedite the software testing life cycle. Topics covered include the seamless integration process, practical use cases, and the benefits of harnessing AI-driven automation for UiPath testing initiatives. By attending this webinar, testers, and automation professionals can gain valuable insights into harnessing the power of AI to optimize their test automation workflows within the UiPath ecosystem, ultimately driving efficiency and quality in software development processes.
What will you get from this session?
1. Insights into integrating generative AI.
2. Understanding how this integration enhances test automation within the UiPath platform
3. Practical demonstrations
4. Exploration of real-world use cases illustrating the benefits of AI-driven test automation for UiPath
Topics covered:
What is generative AI
Test Automation with generative AI and Open AI.
UiPath integration with generative AI
Speaker:
Deepak Rai, Automation Practice Lead, Boundaryless Group and UiPath MVP
In the rapidly evolving landscape of technologies, XML continues to play a vital role in structuring, storing, and transporting data across diverse systems. The recent advancements in artificial intelligence (AI) present new methodologies for enhancing XML development workflows, introducing efficiency, automation, and intelligent capabilities. This presentation will outline the scope and perspective of utilizing AI in XML development. The potential benefits and the possible pitfalls will be highlighted, providing a balanced view of the subject.
We will explore the capabilities of AI in understanding XML markup languages and autonomously creating structured XML content. Additionally, we will examine the capacity of AI to enrich plain text with appropriate XML markup. Practical examples and methodological guidelines will be provided to elucidate how AI can be effectively prompted to interpret and generate accurate XML markup.
Further emphasis will be placed on the role of AI in developing XSLT, or schemas such as XSD and Schematron. We will address the techniques and strategies adopted to create prompts for generating code, explaining code, or refactoring the code, and the results achieved.
The discussion will extend to how AI can be used to transform XML content. In particular, the focus will be on the use of AI XPath extension functions in XSLT, Schematron, Schematron Quick Fixes, or for XML content refactoring.
The presentation aims to deliver a comprehensive overview of AI usage in XML development, providing attendees with the necessary knowledge to make informed decisions. Whether you’re at the early stages of adopting AI or considering integrating it in advanced XML development, this presentation will cover all levels of expertise.
By highlighting the potential advantages and challenges of integrating AI with XML development tools and languages, the presentation seeks to inspire thoughtful conversation around the future of XML development. We’ll not only delve into the technical aspects of AI-powered XML development but also discuss practical implications and possible future directions.
UiPath Test Automation using UiPath Test Suite series, part 5DianaGray10
Welcome to UiPath Test Automation using UiPath Test Suite series part 5. In this session, we will cover CI/CD with devops.
Topics covered:
CI/CD with in UiPath
End-to-end overview of CI/CD pipeline with Azure devops
Speaker:
Lyndsey Byblow, Test Suite Sales Engineer @ UiPath, Inc.
For the full video of this presentation, please visit: https://www.edge-ai-vision.com/2024/06/building-and-scaling-ai-applications-with-the-nx-ai-manager-a-presentation-from-network-optix/
Robin van Emden, Senior Director of Data Science at Network Optix, presents the “Building and Scaling AI Applications with the Nx AI Manager,” tutorial at the May 2024 Embedded Vision Summit.
In this presentation, van Emden covers the basics of scaling edge AI solutions using the Nx tool kit. He emphasizes the process of developing AI models and deploying them globally. He also showcases the conversion of AI models and the creation of effective edge AI pipelines, with a focus on pre-processing, model conversion, selecting the appropriate inference engine for the target hardware and post-processing.
van Emden shows how Nx can simplify the developer’s life and facilitate a rapid transition from concept to production-ready applications.He provides valuable insights into developing scalable and efficient edge AI solutions, with a strong focus on practical implementation.
2. 1. Cubic EoS:
A. SRK EoS
B. PR EoS
C. Other Cubic EoS
2. Non Cubic EoS
3. EoS for Mixtures
4. Hydrocarbons
A. Components
B. Mixtures
C. Heavy Oil
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
2
5. Performing
Phase Equilibrium Calculations
To perform phase equilibrium calculations on a
reservoir fluid composition using a cubic equation
of state,
The critical temperature (T c),
The critical pressure (P c), and
The acentric factor (ω),
Are required for each component contained in the
mixture.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
5
6. Performing
Phase Equilibrium Calculations (Cont.)
In addition, a binary interaction parameter (k ij) is
needed for each pair of components.
If an equation of state with volume correction is
used (e.g., Peneloux et al., 1982),
A volume shift parameter must further be assigned to
each component.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
6
7. Fluid Phase Equilibria in
Multicomponent Systems
In the chemical process industries, fluid mixtures
are often separated into their components by
diffusional operations such as distillation,
absorption, and extraction.
Design of such separation operations requires
quantitative estimates of the partial equilibrium
properties of fluid mixtures.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
7
8. Differences between Phase
Equilibrium and Typical Properties
There is an important difference between
calculating phase equilibrium compositions and
calculating typical volumetric, energetic, or
transport properties of fluids of known
composition.
In the latter case we are interested in the property of the
mixture as a whole, whereas in the former we are
interested in the partial properties of the individual
components which constitute the mixture.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
8
9. Phase Equilibrium vs.
Typical Properties
For example, to find the pressure drop of a liquid
mixture flowing through a pipe, we need the
viscosity and the density of that liquid mixture at
the particular composition of interest.
But if we ask for the composition of the vapor
which is in equilibrium with the liquid mixture, it is
no longer sufficient to know the properties of the
liquid mixture at that particular composition;
We must now know, in addition, how certain of its
properties (in particular the Gibbs energy) depend on
composition.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
9
10. Partial Properties in
Phase Equilibrium Calculations
In phase equilibrium calculations, we must know
partial properties, and to find them, we typically
differentiate data with respect to composition.
Since partial, rather than total, properties are
needed in phase equilibria, it is not surprising that
phase equilibrium calculations are often more
difficult and less accurate than those for other
properties encountered in chemical process design.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
10
11. Thermodynamics of
Vapor-Liquid Equilibria
We are concerned with
A liquid mixture that, at temperature T and pressure P, is
in equilibrium
With a vapor mixture at the same temperature and
pressure.
The quantities of interest are the temperature, the
pressure, and the compositions of both phases.
Given some of these quantities, our task is to calculate
the others.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
11
12. Condition of
thermodynamic Equilibrium
For every component i in the mixture, the condition of
thermodynamic equilibrium is given by
𝒇 𝒊𝑽 = 𝒇 𝒊𝑳
Where f=fugacity, V=Vapor, L= liquid
The fundamental problem is to relate these fugacities
to mixture composition.
The fugacity of a component in a mixture depends on
the temperature, pressure, and composition of that
mixture. In principle any measure of composition can
be used. For the vapor phase, the composition is nearly
always expressed by the mole fraction y.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
12
13. Vapor-Liquid Equilibria with EoS
Thermodynamics provides the basis for using EoS
not only for the calculation of the PVT relations and
the caloric property relations, but, EoS can also be
used for computing phase equilibria among fluid
phases.
The basis is below equation with vapor and liquid
fugacity coefficients:
𝒇 𝒊𝑽 = 𝒚 𝒊 𝝓 𝒊𝑽 𝑷 = 𝒙 𝒊 𝝓 𝒊𝑳 𝑷 = 𝒇 𝒊𝑳
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
13
14. Vapor-Liquid Equilibria with EoS
(Cont.)
The K-factor commonly used in calculations for
process simulators is then simply related to the
fugacity coefficients
𝒚𝒊
𝝓 𝒊𝑳
𝑲𝒊 = = 𝑽
𝒙𝒊
𝝓𝒊
To obtain ϕ iV, we need the vapor composition, y, and
volume, VV,
While for the liquid phase, ϕ iL is found using the liquid
composition, x, and volume, VL.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
14
15. Vapor-Liquid Equilibria with EoS
(Cont.)
Since state conditions are usually specified by T and
P, the volumes must be found by solving the PVT
relationship of the EoS.
𝑷 = 𝑷 𝑻, 𝑽 𝑽 , 𝒚 = 𝑷(𝑻, 𝑽 𝑳 , 𝒙
In principle, these Equations are sufficient to find
all K factors in a multicomponent system of two or
more phases.
One difficulty is that EoS relations are highly
nonlinear and thus can require sophisticated
numerical initialization and convergence methods
to obtain final solutions.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
15
16. Case Sample
To fix ideas, consider a two-phase (vapor-liquid)
system containing m components at a fixed total
pressure P. The mole fractions in the liquid phase
are x1, x2, . . . , x (m-1).
We want to find the bubble-point temperature T
and the vapor phase mole fractions y1, y2, . . . , y
(m-1). The total number of unknowns, therefore, is
m.
However, to obtain ϕ iV and ϕ iL, we also must
know the molar volumes VL and VV. Therefore, the
total number of unknowns is m + 2.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
16
17. Case Sample (Cont.)
To find m + 2 unknowns, we require m + 2
independent equations. These are:
(Ki=yi/xi=ϕ iL/ϕ iV) Equation for each component i: m
equations
(P=P (T, V^V, y) =P (T, V^L, x)) Equation, once for the
vapor phase and once for the liquid phase: 2 equations
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
17
18. Other Common Cases
This case, in which P and x are given and T and y
are to be found, is called a bubble-point T problem.
Other common cases are:
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
18
19. ‘‘Flash’’ Problem
However, the most common way to calculate phase
equilibria in process design and simulation is to
solve the ‘‘flash’’ problem.
In this case, we are given P, T, and the mole fractions, z,
of a feed to be split into fractions α of vapor and (1 - α)
of liquid.
We cannot go into details about the procedure
here.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
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20.
21.
22. Tc, Pc, and ω Calculation for
Defined Components
Tc, Pc, and ω of the defined
components can be determined
experimentally and the
experimental values looked up in
textbooks on applied
thermodynamics.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
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23. Tc, Pc, and ω Calculation for
C7+ Fractions
A C7+ fraction will typically contain paraffinic (P),
naphthenic (N), and aromatic (A) compounds.
It is seen that the density increases in the order paraffin
(P), naphthene (N), and aromatic (A).
The density is therefore a good measure of the PNA
distribution.
T c (K), P c (atm), and ω of a carbon number
fraction are expressed in terms of its molecular
weight, M (g/mol), and density, ρ (g/cm 3 ), at
atmospheric conditions
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
23
24. Tc, Pc, and ω Calculation
for Plus Fraction
Characterization of the plus fraction involves
Estimation of the molar distribution,
i.e., mole fraction vs. carbon number.
Estimation of Tc, Pc, and ω of the resulting carbon
number fractions.
Lumping of the carbon number fractions into a
reasonable number of pseudocomponents.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
24
25. Binary Interaction Coefficients
To determine the parameter a in a cubic equation of
state as, for example, the SRK or PR equation, it is
necessary to know a binary interaction parameter, kij,
for each binary component pair, i.e., for any
components i and j.
kij is usually also assumed to be equal to or close to
zero for two different components of approximately the
same polarity.
As hydrocarbons are essentially nonpolar compounds, kij = 0
is a reasonable approximation for all hydrocarbon binaries.
The nonhydrocarbons contained in petroleum reservoir fluids
are usually limited to N2, CO2, and H2S. It can further be of
interest to consider H2O.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
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26. Lumping
The characterized mixture consists of more than 80
components and pseudocomponents. It is desirable
to reduce this number before performing phase
equilibrium calculations.
Lumping consists of
Deciding what carbon number fractions to lump (group)
into the same pseudocomponent.
Averaging Tc, Pc, and ω of the individual carbon number
fractions to one Tc, Pc, and ω representative for the
whole lumped pseudocomponent.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
26
29. Another Characterization and Lumping of
a Sample Mixture
Table shows composition after
characterization and lumping into a
total of six pseudocomponents.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
29
30.
31. Delumping
Compositional reservoir simulation studies are
often quite time consuming, and the simulation
time increases with the number of components.
Compositions used in compositional reservoir
simulation studies are therefore often heavily
lumped. Also, some of the defined components are
usually lumped in a compositional reservoir
simulation.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
31
32. Delumping (Cont.)
In a process plant separating a produced well
stream into gas and oil, the pressure is usually
much lower than in the reservoir.
A lumping that was justified for reservoir
conditions is not necessarily justified for process
conditions.
It would therefore be interesting with a procedure,
which in a meaningful manner could split a lumped
composition from a compositional reservoir
simulation into its original constituents. Such split is
called delumping.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
32
33. K-Factor
In a PT flash for a hydrocarbon mixture, the relative
molar amounts of a component i ending up in the
gas and liquid phases are determined by the Kfactor of each component
𝒚𝒊
𝑲𝒊 =
𝒙𝒊
Where yi is the mole fraction of component i in the gas
phase and
xi the mole fraction of component i in the liquid phase.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
33
34. Connection between K-Factor and
Delumping
If two components i and j have approximately the
same K-factor, it is justified to lump them together
to one pseudocomponent before performing the
flash.
The K-factor of the lumped component will be
approximately the same as the K-factors of the two
components treated individually.
Flash calculations are carried out for a heavily
lumped fluid and the resulting phase compositions
delumped after each flash calculation using an
appropriate K-factor correlation.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
34
35. 1. Pedersen, K.S., Christensen, P.L., and Azeem,
S.J. (2006). Phase behavior of petroleum
reservoir fluids (CRC Press). Ch5.
2. Poling, B.E., Prausnitz, J.M., John Paul, O., and
Reid, R.C. (2001). The properties of gases and
liquids (McGraw-Hill New York). Ch8.
2013 H. AlamiNia
Reservoir Fluid Properties Course: Equilibrium
35