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 provides an overview of reservoir engineering concepts related to coning and critical flow rates in vertical wells. It discusses various empirical correlations that can be used to predict critical oil rates for gas, water, and combined gas-water coning scenarios. These include correlations developed by Meyer-Garder, Chierici-Ciucci, Hoyland-Papatzacos-Skjaeveland, Chaney et al., Chaperson, and Schols. It also covers breakthrough time correlations and methods for predicting water production performance and the rise of the oil-water contact after breakthrough occurs.
- Reservoirs are classified based on the composition of hydrocarbons present, initial reservoir pressure and temperature, and the pressure and temperature of produced fluids.
- A pressure-temperature diagram is used to classify reservoirs and describe the phase behavior of reservoir fluids, delineating the liquid, gas, and two-phase regions.
- Based on the diagram, reservoirs are classified as oil reservoirs if the temperature is below the critical temperature, and gas reservoirs if above the critical temperature.
Selection of the best artificial lift systems for the well depend on location, depth, estimated production, reservoir properties, and many other factors. Here is an overview on selection criteria for the best results
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
Master class presentation on artificial lift screening and selection. Prepared for Praxis' Interactive Technology Workshop on Artificial Lift, Dubai, September 2013.
This document provides information about reservoir engineering. It discusses how reservoir engineers use tools like subsurface geology, mathematics, and physics/chemistry to understand fluid behavior in reservoirs. It also describes different well classes used for injection/extraction, environmental impacts of enhanced oil recovery, and various reservoir engineering techniques like simulation modeling, production surveillance, and evaluating volumetric sweep efficiency. Thermal and chemical enhanced oil recovery methods are explained, including gas, steam, polymer, surfactant, microbial and in-situ combustion injection.
The document discusses well deliverability and pressure drop in oil and gas wells. It explains that pressure drop is affected by properties of the reservoir fluids, production rates, and the mechanical configuration of the wellbore. Pressure loss is highest in the tubing and can be estimated using charts, correlations, or equations that consider fluid properties, flow rates, and well geometry. Matching inflow and outflow pressures gives the stabilized flow rate. The document compares methods for estimating pressure drop in single-phase and multiphase flow.
This document provides an overview of reservoir engineering concepts related to coning and critical flow rates in vertical wells. It discusses various empirical correlations that can be used to predict critical oil rates for gas, water, and combined gas-water coning scenarios. These include correlations developed by Meyer-Garder, Chierici-Ciucci, Hoyland-Papatzacos-Skjaeveland, Chaney et al., Chaperson, and Schols. It also covers breakthrough time correlations and methods for predicting water production performance and the rise of the oil-water contact after breakthrough occurs.
- Reservoirs are classified based on the composition of hydrocarbons present, initial reservoir pressure and temperature, and the pressure and temperature of produced fluids.
- A pressure-temperature diagram is used to classify reservoirs and describe the phase behavior of reservoir fluids, delineating the liquid, gas, and two-phase regions.
- Based on the diagram, reservoirs are classified as oil reservoirs if the temperature is below the critical temperature, and gas reservoirs if above the critical temperature.
Selection of the best artificial lift systems for the well depend on location, depth, estimated production, reservoir properties, and many other factors. Here is an overview on selection criteria for the best results
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
Master class presentation on artificial lift screening and selection. Prepared for Praxis' Interactive Technology Workshop on Artificial Lift, Dubai, September 2013.
This document provides information about reservoir engineering. It discusses how reservoir engineers use tools like subsurface geology, mathematics, and physics/chemistry to understand fluid behavior in reservoirs. It also describes different well classes used for injection/extraction, environmental impacts of enhanced oil recovery, and various reservoir engineering techniques like simulation modeling, production surveillance, and evaluating volumetric sweep efficiency. Thermal and chemical enhanced oil recovery methods are explained, including gas, steam, polymer, surfactant, microbial and in-situ combustion injection.
The document discusses well deliverability and pressure drop in oil and gas wells. It explains that pressure drop is affected by properties of the reservoir fluids, production rates, and the mechanical configuration of the wellbore. Pressure loss is highest in the tubing and can be estimated using charts, correlations, or equations that consider fluid properties, flow rates, and well geometry. Matching inflow and outflow pressures gives the stabilized flow rate. The document compares methods for estimating pressure drop in single-phase and multiphase flow.
This document provides an overview of reservoir engineering concepts related to oil recovery from waterflooding. It discusses that the overall recovery efficiency from waterflooding is calculated as the product of displacement efficiency, areal sweep efficiency, and vertical sweep efficiency. Displacement efficiency refers to the fraction of movable oil recovered from the swept region. Areal and vertical sweep efficiencies refer to the fractional area and vertical section of the reservoir that is contacted by the injected water. The document also examines factors that influence sweep efficiencies such as reservoir heterogeneity, mobility ratio, flooding pattern, and injection volume.
Field Development Project : Gelama MerahHami Asma'i
A green field development project located in Sabah Basin comprises the whole upstream field development cycle from geology, reservoir studies to production facilities and economics. The objective is to come out with the best strategy to develop the field starting from our very own effort of reservoir characterization out of log and core data. Under supervision of lecturers, this project was completed as per scheduled.
Among new technical methodologies applied upon the completion this project:
1. Cubic Spline Interpolation Method in bulk volume calculation
2. Monte Carlo probabilistic method in reserve estimation
3. Reservoir Opportunity Index (ROI) method in well placement
Project was assessed by PETRONAS custodians.
This document discusses well testing and well test analysis software programs. It provides information on:
- The objectives of well testing including identifying fluid types and reservoir parameters
- Types of well tests including productivity tests for development wells and descriptive tests for exploration wells
- Popular well test software programs for analytical and numerical analysis including Saphir, PanSystem, Interpret 2000, and Weltest 200
- An overview of the Weltest 200 program which links analytical and numerical well test analysis through different modules
- Using an example of liquid productivity or IPR testing to demonstrate how well test data is incorporated and analyzed in the software
This 5 day training course is designed to give you a comprehensive account of methods and techniques used in modern well testing and analysis. Subsequently to outlining well test objectives and general methodologies applied, the course will provide real case studies and practice using modern software for Pressure Transient Analysis. These exercises will demonstrate clearly the limitations, assumptions and applicability of various techniques applied in the field.
Introduction Effective Permeability & Relative PermeabilityM.T.H Group
Effective and relative permeability data are used to quantify fluid flow in reservoirs containing multiple phases. Effective permeability measures the flow of a single phase in a multi-phase system, while relative permeability expresses effective permeability as a ratio of absolute permeability. Relative permeability curves describe how the flow of each phase varies with saturation. They are influenced by factors like pore structure, wettability, and saturation history, and are important inputs for reservoir simulation and other multiphase flow calculations.
- The document discusses reservoir characteristics including rock and fluid properties that are important to understand for optimal hydrocarbon recovery. Techniques like seismic data, well logging, and testing provide valuable data to build reservoir models.
- Key rock properties that impact hydrocarbon storage and flow include porosity, permeability, and wettability. Core analysis in the lab and well logs provide data on these properties.
- Understanding fluid properties like phase behavior under reservoir conditions of pressure and temperature is also important for predicting production performance and fluid composition.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
The document discusses various natural reservoir drive mechanisms that provide energy for hydrocarbon production including:
1) Solution gas drive where dissolved gas expands due to pressure drop, providing 5-25% oil recovery.
2) Gas cap drive where free gas expansion drives production, providing 20-40% oil recovery.
3) Water drive where aquifer water influx provides pressure to displace oil, providing 35-75% oil recovery.
4) Gravity drainage where gas migrates updip and oil downdip in high dip reservoirs.
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
This document discusses key properties of crude oil, including:
1) Oil is classified based on properties like specific gravity, viscosity, density, etc. with specific gravity and viscosity most commonly used. Specific gravity is represented by API gravity which ranges from 8 to 58 degrees.
2) Bubble point pressure is the pressure at which a small amount of gas is in equilibrium with oil. When pressure drops below this point, gas is liberated from the oil.
3) Other properties discussed include formation volume factor (ratio of reservoir to surface volumes), solution gas-oil ratio (amount of gas dissolved in oil), and compressibility (change in volume with pressure change).
The document discusses formation damage in oil and gas wells. It defines formation damage as a reduction in permeability of the reservoir rock surrounding the wellbore. Several mechanisms of formation damage are described, including plugging by solids, clay swelling, saturation changes, and bacterial growth. Methods for evaluating formation damage in the field include well testing, downhole video, sampling fluids and solids, and coring. The concept of skin factor is introduced to quantify the level of damage. Laboratory studies on formation damage at different drilling environments are also summarized.
Petroleum reservoirs are classified as either oil or gas reservoirs based on reservoir temperature relative to critical temperature. Within these broad classifications, reservoirs can be further classified. Oil reservoirs have temperature below critical temperature, while gas reservoirs have temperature above critical. Specific gas reservoir classifications include retrograde, near-critical, wet and dry based on phase behavior and GOR. Retrograde reservoirs have unique condensation behavior on pressure depletion. Classification is important for understanding reservoir fluid properties, production behavior, and development approach.
Analyzing Multi-zone completion using multilayer by IPR (PROSPER) Arez Luqman
The primary objective of any well drilled and completed is to produce Hydrocarbons; by loading the Hydrocarbon (i.e. Oil and Gas) contained within the well through a conduit of the well and start separating it with surface facilities depending on type and composition of the Hydrocarbon.
Producing oil is simultaneously contained with problems depending on the type and properties of the reservoir.
Furthermore, what makes the problems much more; is when oil and/or gas is produced from multi-zones at the same time, when accumulated problems from all the producer zones occurring at the same time.
To help analyze this problems we are going to use PROSPER software package IPR multilayer, in which helps in identifying the relationship between Flow rate and Reservoir pressure.
Production Optimization using nodal analysis. The nodal systems analysis approach is a very flexible method
that can be used to improve the performance of many well
systems. The nodal systems analysis approach may be used to analyze
many producing oil and gas well problems. The procedure can
be applied to both flowing and artificial
This document provides an overview of reservoir engineering fundamentals including:
- Three types of reservoir fluids based on compressibility: incompressible, slightly compressible, and compressible.
- Three flow regimes in reservoirs: steady-state, unsteady-state, and pseudosteady-state.
- Common reservoir geometries that influence fluid flow including radial, linear, spherical, and hemispherical.
- Darcy's law and its applications to steady-state fluid flow in reservoirs, including for different fluid types and geometries.
This document discusses laboratory experiments for analyzing reservoir fluid properties, including differential liberation (vaporization) tests and separator tests. Differential liberation tests measure properties such as gas and oil volumes, densities, and compositions as pressure is reduced, better simulating reservoir separation. Separator tests determine volumetric behavior as fluids pass through surface separation, providing data to optimize conditions and calculate petroleum engineering parameters. The document explains procedures, calculations, and objectives of the tests.
This document discusses various artificial lift methods used to increase production from oil and gas wells as reservoir pressure declines. It describes the basic principles and components of common artificial lift techniques, including sucker rod pumps, gas lift, electrical submersible pumps, hydraulic jet pumping, plunger lift, and progressive cavity pumping. For each method, it provides information on advantages, limitations, and typical application ranges for operating parameters such as depth, production rate, temperature, and wellbore geometry. The document aims to provide an overview of different artificial lift options and considerations for selecting the appropriate production method.
Nodal Analysis introduction to inflow and outflow performance - nextgusgon
This document discusses nodal analysis concepts for analyzing inflow and outflow performance in fluid systems. It introduces key terms like nodal analysis, inflow, outflow, upstream and downstream components, and graphical solutions. It provides an example problem calculating system capacity and the impact of changing pipe diameters. It also covers topics like single-phase and multiphase fluid flow, flow regimes, flow patterns, and calculating pressure drops and flow performance in pipes.
Artificial lift technology uses mechanical devices like pumps or velocity strings to increase the flow of liquids like oil or water from production wells. Artificial lift is needed when reservoir pressure is insufficient to lift fluids to the surface. Common artificial lift systems include reciprocating rod lift, progressing cavity pumping, hydraulic lift, gas lift, plunger lift, and electric submersible pumping. The appropriate system depends on factors like well characteristics, reservoir properties, fluids, surface constraints, and economics. Key components include pumping units, motors, sucker rods, pumps and accessories. Benefits include flexibility and ability to optimize production levels. Limitations depend on the specific system but may include depth rating, temperature sensitivity, fluid properties, or need for a
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
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.
This document provides an overview of reservoir engineering concepts related to oil recovery from waterflooding. It discusses that the overall recovery efficiency from waterflooding is calculated as the product of displacement efficiency, areal sweep efficiency, and vertical sweep efficiency. Displacement efficiency refers to the fraction of movable oil recovered from the swept region. Areal and vertical sweep efficiencies refer to the fractional area and vertical section of the reservoir that is contacted by the injected water. The document also examines factors that influence sweep efficiencies such as reservoir heterogeneity, mobility ratio, flooding pattern, and injection volume.
Field Development Project : Gelama MerahHami Asma'i
A green field development project located in Sabah Basin comprises the whole upstream field development cycle from geology, reservoir studies to production facilities and economics. The objective is to come out with the best strategy to develop the field starting from our very own effort of reservoir characterization out of log and core data. Under supervision of lecturers, this project was completed as per scheduled.
Among new technical methodologies applied upon the completion this project:
1. Cubic Spline Interpolation Method in bulk volume calculation
2. Monte Carlo probabilistic method in reserve estimation
3. Reservoir Opportunity Index (ROI) method in well placement
Project was assessed by PETRONAS custodians.
This document discusses well testing and well test analysis software programs. It provides information on:
- The objectives of well testing including identifying fluid types and reservoir parameters
- Types of well tests including productivity tests for development wells and descriptive tests for exploration wells
- Popular well test software programs for analytical and numerical analysis including Saphir, PanSystem, Interpret 2000, and Weltest 200
- An overview of the Weltest 200 program which links analytical and numerical well test analysis through different modules
- Using an example of liquid productivity or IPR testing to demonstrate how well test data is incorporated and analyzed in the software
This 5 day training course is designed to give you a comprehensive account of methods and techniques used in modern well testing and analysis. Subsequently to outlining well test objectives and general methodologies applied, the course will provide real case studies and practice using modern software for Pressure Transient Analysis. These exercises will demonstrate clearly the limitations, assumptions and applicability of various techniques applied in the field.
Introduction Effective Permeability & Relative PermeabilityM.T.H Group
Effective and relative permeability data are used to quantify fluid flow in reservoirs containing multiple phases. Effective permeability measures the flow of a single phase in a multi-phase system, while relative permeability expresses effective permeability as a ratio of absolute permeability. Relative permeability curves describe how the flow of each phase varies with saturation. They are influenced by factors like pore structure, wettability, and saturation history, and are important inputs for reservoir simulation and other multiphase flow calculations.
- The document discusses reservoir characteristics including rock and fluid properties that are important to understand for optimal hydrocarbon recovery. Techniques like seismic data, well logging, and testing provide valuable data to build reservoir models.
- Key rock properties that impact hydrocarbon storage and flow include porosity, permeability, and wettability. Core analysis in the lab and well logs provide data on these properties.
- Understanding fluid properties like phase behavior under reservoir conditions of pressure and temperature is also important for predicting production performance and fluid composition.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
The document discusses various natural reservoir drive mechanisms that provide energy for hydrocarbon production including:
1) Solution gas drive where dissolved gas expands due to pressure drop, providing 5-25% oil recovery.
2) Gas cap drive where free gas expansion drives production, providing 20-40% oil recovery.
3) Water drive where aquifer water influx provides pressure to displace oil, providing 35-75% oil recovery.
4) Gravity drainage where gas migrates updip and oil downdip in high dip reservoirs.
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
This document discusses key properties of crude oil, including:
1) Oil is classified based on properties like specific gravity, viscosity, density, etc. with specific gravity and viscosity most commonly used. Specific gravity is represented by API gravity which ranges from 8 to 58 degrees.
2) Bubble point pressure is the pressure at which a small amount of gas is in equilibrium with oil. When pressure drops below this point, gas is liberated from the oil.
3) Other properties discussed include formation volume factor (ratio of reservoir to surface volumes), solution gas-oil ratio (amount of gas dissolved in oil), and compressibility (change in volume with pressure change).
The document discusses formation damage in oil and gas wells. It defines formation damage as a reduction in permeability of the reservoir rock surrounding the wellbore. Several mechanisms of formation damage are described, including plugging by solids, clay swelling, saturation changes, and bacterial growth. Methods for evaluating formation damage in the field include well testing, downhole video, sampling fluids and solids, and coring. The concept of skin factor is introduced to quantify the level of damage. Laboratory studies on formation damage at different drilling environments are also summarized.
Petroleum reservoirs are classified as either oil or gas reservoirs based on reservoir temperature relative to critical temperature. Within these broad classifications, reservoirs can be further classified. Oil reservoirs have temperature below critical temperature, while gas reservoirs have temperature above critical. Specific gas reservoir classifications include retrograde, near-critical, wet and dry based on phase behavior and GOR. Retrograde reservoirs have unique condensation behavior on pressure depletion. Classification is important for understanding reservoir fluid properties, production behavior, and development approach.
Analyzing Multi-zone completion using multilayer by IPR (PROSPER) Arez Luqman
The primary objective of any well drilled and completed is to produce Hydrocarbons; by loading the Hydrocarbon (i.e. Oil and Gas) contained within the well through a conduit of the well and start separating it with surface facilities depending on type and composition of the Hydrocarbon.
Producing oil is simultaneously contained with problems depending on the type and properties of the reservoir.
Furthermore, what makes the problems much more; is when oil and/or gas is produced from multi-zones at the same time, when accumulated problems from all the producer zones occurring at the same time.
To help analyze this problems we are going to use PROSPER software package IPR multilayer, in which helps in identifying the relationship between Flow rate and Reservoir pressure.
Production Optimization using nodal analysis. The nodal systems analysis approach is a very flexible method
that can be used to improve the performance of many well
systems. The nodal systems analysis approach may be used to analyze
many producing oil and gas well problems. The procedure can
be applied to both flowing and artificial
This document provides an overview of reservoir engineering fundamentals including:
- Three types of reservoir fluids based on compressibility: incompressible, slightly compressible, and compressible.
- Three flow regimes in reservoirs: steady-state, unsteady-state, and pseudosteady-state.
- Common reservoir geometries that influence fluid flow including radial, linear, spherical, and hemispherical.
- Darcy's law and its applications to steady-state fluid flow in reservoirs, including for different fluid types and geometries.
This document discusses laboratory experiments for analyzing reservoir fluid properties, including differential liberation (vaporization) tests and separator tests. Differential liberation tests measure properties such as gas and oil volumes, densities, and compositions as pressure is reduced, better simulating reservoir separation. Separator tests determine volumetric behavior as fluids pass through surface separation, providing data to optimize conditions and calculate petroleum engineering parameters. The document explains procedures, calculations, and objectives of the tests.
This document discusses various artificial lift methods used to increase production from oil and gas wells as reservoir pressure declines. It describes the basic principles and components of common artificial lift techniques, including sucker rod pumps, gas lift, electrical submersible pumps, hydraulic jet pumping, plunger lift, and progressive cavity pumping. For each method, it provides information on advantages, limitations, and typical application ranges for operating parameters such as depth, production rate, temperature, and wellbore geometry. The document aims to provide an overview of different artificial lift options and considerations for selecting the appropriate production method.
Nodal Analysis introduction to inflow and outflow performance - nextgusgon
This document discusses nodal analysis concepts for analyzing inflow and outflow performance in fluid systems. It introduces key terms like nodal analysis, inflow, outflow, upstream and downstream components, and graphical solutions. It provides an example problem calculating system capacity and the impact of changing pipe diameters. It also covers topics like single-phase and multiphase fluid flow, flow regimes, flow patterns, and calculating pressure drops and flow performance in pipes.
Artificial lift technology uses mechanical devices like pumps or velocity strings to increase the flow of liquids like oil or water from production wells. Artificial lift is needed when reservoir pressure is insufficient to lift fluids to the surface. Common artificial lift systems include reciprocating rod lift, progressing cavity pumping, hydraulic lift, gas lift, plunger lift, and electric submersible pumping. The appropriate system depends on factors like well characteristics, reservoir properties, fluids, surface constraints, and economics. Key components include pumping units, motors, sucker rods, pumps and accessories. Benefits include flexibility and ability to optimize production levels. Limitations depend on the specific system but may include depth rating, temperature sensitivity, fluid properties, or need for a
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
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.
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.
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.
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.
This document provides an overview of a reservoir fluid properties course for petroleum engineering students. The 2-credit, weekly course aims to describe how oil and gas behave under different conditions. Lectures will be divided into two 50-slide sections with a short break. Students will be assessed based on class activities, a midterm exam, and a final exam. The 16-lecture course will cover topics like phase behavior of hydrocarbons, PVT experiments, equations of state, fluid properties, and relevant software. The course is designed to help students understand how reservoir fluids are modeled and their importance in petroleum engineering.
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 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 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 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 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.
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.
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 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 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 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 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 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.
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 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.
This document discusses the behavior of real gases and how they differ from ideal gases. Real gases deviate more from ideal gas behavior at higher pressures and temperatures due to molecular interactions. Equations of state have been developed to better model real gas behavior using factors like compressibility and deviation from ideality. The z-factor relates the actual volume of real gases to the ideal gas volume at the same conditions. Charts have been created to estimate z-factors based on reduced properties and gas composition. Examples are provided to calculate z-factors for initial reservoir conditions using these charts and correlations.
This document provides an overview of methods for calculating gas properties including:
1. Empirical correlations for calculating z-factors such as Hall-Yarborough and Dranchuk-Abu-Kassem.
2. Calculation of gas compressibility, gas formation volume factor, and gas expansion factor using real gas equations of state.
3. Empirical correlations for calculating gas viscosity including Carr-Kobayashi-Burrows and Lee-Gonzalez-Eakin.
This document provides an overview of methods for calculating natural gas properties including:
1. Empirical correlations for calculating gas compressibility factors such as Hall-Yarborough, Dranchuk-Abu-Kassem, and Dranchuk-Purvis-Robinson.
2. Calculation of gas formation volume factor and gas expansion factor from gas compressibility factors and properties.
3. Empirical correlations for calculating gas viscosity including Carr-Kobayashi-Burrows and Lee-Gonzalez-Eakin.
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.
The properties of a gas mixture depend on the properties of its individual components and their relative amounts. There are two ways to describe the composition of a mixture: molar analysis specifies the moles of each component, and gravimetric analysis specifies the mass of each component. For ideal gas mixtures, Dalton's law and Amagat's law can be used to determine pressure and volume behavior. For real gas mixtures, these laws are approximate and equations of state must be used. The properties of gas mixtures can be determined by weighted averages of the component properties.
This document discusses properties of natural gases that are important for engineers to understand when designing equipment for natural gas production, processing, and transportation. It covers topics such as the molecular theory of gases and liquids, equations of state including the ideal gas law and real gas behavior, viscosity, thermodynamic properties including specific heat and heating values, and limits of flammability and safety considerations. Key equations of state and models for predicting properties like compressibility factor, viscosity, and specific heat are presented.
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.
1) The document discusses properties of pure substances and how they are presented in tables. It focuses on water properties and steam tables.
2) It explains different phases like saturated liquid, saturated vapor, superheated vapor, and compressed liquid. It also discusses quality and using tables to find properties through interpolation.
3) The ideal gas equation of state is presented along with when it can be applied to water vapor. The compressibility factor is introduced as a measure of how gases deviate from ideal behavior.
This document discusses fundamentals of chemical engineering related to single-phase systems and ideal gases. It includes:
1) Descriptions of liquid and solid densities, and how they are relatively independent of temperature and pressure changes.
2) Derivation of the ideal gas equation of state from kinetic theory, and examples of using the equation to calculate properties like volume and molar flow rates.
3) Introduction of the compressibility factor and using generalized compressibility charts to estimate non-ideal gas behavior based on reduced temperature and pressure.
ME6301 ENGINEERING THERMODYNAMICS SHORT QUESTIONS AND ANSWERS - UNIT IVBIBIN CHIDAMBARANATHAN
This document contains a compilation of concepts related to ideal gases, real gases, and thermodynamic relations for a Mechanical Engineering course. It defines ideal gases as having no intermolecular forces and real gases as having small intermolecular forces at high temperatures and low pressures. Key concepts summarized include the gas laws, equations of state, reduced properties, partial pressures, compressibility factor, and thermodynamic properties.
A density correction for the peng robinson equationLuis Follegatti
This document presents a density correction for the Peng-Robinson equation of state. The correction involves adding a simple empirical term that requires one parameter per component. It improves the prediction of liquid densities by 2-4% and vapor densities slightly. The correction retains the internal consistency between vapor and liquid properties predicted by equations of state. It provides a reliable way to enhance density predictions without significantly affecting other properties.
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 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.
1. This document discusses the kinetic molecular theory and properties of ideal gases. It introduces concepts such as average kinetic energy, Maxwell speed distribution curves, and the ideal gas law.
2. Several gas laws are described, including Boyle's law, Charles' law, Avogadro's law, and Dalton's law of partial pressures. Standard temperature and pressure is defined.
3. Deviations from ideal gas behavior occur at high pressures due to intermolecular forces and the non-negligible volume of gas particles. Real gases behave more ideally at lower pressures.
Gases have no definite volume and assume the volume of any vessel. The behavior of gases is described by gas laws including Boyle's law, Charles' law, Avogadro's law, and the ideal gas law. Real gases deviate from ideal behavior at high pressures and low temperatures and are better described by equations like van der Waals. Key gas properties include gas formation volume factor, gas compressibility factor, gas viscosity, and gas solubility in oil. Gas formation volume factor relates the volume of gas at reservoir conditions to standard surface conditions.
The document discusses key thermodynamic property relations including:
1. The Maxwell relations which relate partial derivatives of properties like pressure, volume, temperature, and entropy.
2. The Clapeyron equation which relates the slope of a saturation curve to enthalpy of vaporization.
3. General relations for changes in internal energy, enthalpy, entropy, and specific heats in terms of pressure, volume, temperature and specific heats.
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 three sections (13.1, 13.2, 13.3) from a chemistry textbook chapter on gases. Section 13.1 describes gas laws including Boyle's law, Charles' law, Gay-Lussac's law, and the combined gas law. Section 13.2 introduces the ideal gas law, Avogadro's principle, and compares real and ideal gases. Section 13.3 explains how to use gas laws and stoichiometry to solve problems involving gaseous reactants and products in chemical equations.
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.
The simplified electron and muon model, Oscillating Spacetime: The Foundation...RitikBhardwaj56
Discover the Simplified Electron and Muon Model: A New Wave-Based Approach to Understanding Particles delves into a groundbreaking theory that presents electrons and muons as rotating soliton waves within oscillating spacetime. Geared towards students, researchers, and science buffs, this book breaks down complex ideas into simple explanations. It covers topics such as electron waves, temporal dynamics, and the implications of this model on particle physics. With clear illustrations and easy-to-follow explanations, readers will gain a new outlook on the universe's fundamental nature.
Walmart Business+ and Spark Good for Nonprofits.pdfTechSoup
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Strategies for Effective Upskilling is a presentation by Chinwendu Peace in a Your Skill Boost Masterclass organisation by the Excellence Foundation for South Sudan on 08th and 09th June 2024 from 1 PM to 3 PM on each day.
LAND USE LAND COVER AND NDVI OF MIRZAPUR DISTRICT, UPRAHUL
This Dissertation explores the particular circumstances of Mirzapur, a region located in the
core of India. Mirzapur, with its varied terrains and abundant biodiversity, offers an optimal
environment for investigating the changes in vegetation cover dynamics. Our study utilizes
advanced technologies such as GIS (Geographic Information Systems) and Remote sensing to
analyze the transformations that have taken place over the course of a decade.
The complex relationship between human activities and the environment has been the focus
of extensive research and worry. As the global community grapples with swift urbanization,
population expansion, and economic progress, the effects on natural ecosystems are becoming
more evident. A crucial element of this impact is the alteration of vegetation cover, which plays a
significant role in maintaining the ecological equilibrium of our planet.Land serves as the foundation for all human activities and provides the necessary materials for
these activities. As the most crucial natural resource, its utilization by humans results in different
'Land uses,' which are determined by both human activities and the physical characteristics of the
land.
The utilization of land is impacted by human needs and environmental factors. In countries
like India, rapid population growth and the emphasis on extensive resource exploitation can lead
to significant land degradation, adversely affecting the region's land cover.
Therefore, human intervention has significantly influenced land use patterns over many
centuries, evolving its structure over time and space. In the present era, these changes have
accelerated due to factors such as agriculture and urbanization. Information regarding land use and
cover is essential for various planning and management tasks related to the Earth's surface,
providing crucial environmental data for scientific, resource management, policy purposes, and
diverse human activities.
Accurate understanding of land use and cover is imperative for the development planning
of any area. Consequently, a wide range of professionals, including earth system scientists, land
and water managers, and urban planners, are interested in obtaining data on land use and cover
changes, conversion trends, and other related patterns. The spatial dimensions of land use and
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these patterns indicate shifts in economic and social conditions. Monitoring such changes with the
help of Advanced technologies like Remote Sensing and Geographic Information Systems is
crucial for coordinated efforts across different administrative levels. Advanced technologies like
Remote Sensing and Geographic Information Systems
9
Changes in vegetation cover refer to variations in the distribution, composition, and overall
structure of plant communities across different temporal and spatial scales. These changes can
occur natural.
Exploiting Artificial Intelligence for Empowering Researchers and Faculty, In...Dr. Vinod Kumar Kanvaria
Exploiting Artificial Intelligence for Empowering Researchers and Faculty,
International FDP on Fundamentals of Research in Social Sciences
at Integral University, Lucknow, 06.06.2024
By Dr. Vinod Kumar Kanvaria
it describes the bony anatomy including the femoral head , acetabulum, labrum . also discusses the capsule , ligaments . muscle that act on the hip joint and the range of motion are outlined. factors affecting hip joint stability and weight transmission through the joint are summarized.
A workshop hosted by the South African Journal of Science aimed at postgraduate students and early career researchers with little or no experience in writing and publishing journal articles.
How to Fix the Import Error in the Odoo 17Celine George
An import error occurs when a program fails to import a module or library, disrupting its execution. In languages like Python, this issue arises when the specified module cannot be found or accessed, hindering the program's functionality. Resolving import errors is crucial for maintaining smooth software operation and uninterrupted development processes.
2. 1. Reservoir Fluid Behaviors
2. Petroleum Reservoirs
A. Oil
B. Gas
3. Introduction to Physical Properties
3. 1. Gas Behavior
2. Gas Properties:
A. Z Factor:
a. Calculation for pure components
b. Calculation for mixture components
I. Mixing rules for calculating pseudocritical properties
II. Correlations for calculating pseudocritical properties
c. Nonhydrocarbon adjustment
d. High molecular weight gases adjustment
4.
5. Reservoir Fluid Properties
To understand and predict the volumetric behavior
of oil and gas reservoirs as a function of pressure,
knowledge of the physical properties of reservoir
fluids must be gained.
These fluid properties are usually determined by
laboratory experiments performed on samples of
actual reservoir fluids.
In the absence of experimentally measured
properties, it is necessary for the petroleum
engineer to determine the properties from
empirically derived correlations.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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6. Natural Gas Constituents
A gas is defined as a homogeneous fluid of low
viscosity and density that has no definite volume
but expands to completely fill the vessel in which it
is placed.
Generally, the natural gas is a mixture of
hydrocarbon and nonhydrocarbon gases.
The hydrocarbon gases that are normally found in a
natural gas are methanes, ethanes, propanes, butanes,
pentanes, and small amounts of hexanes and heavier.
The nonhydrocarbon gases (i.e., impurities) include
carbon dioxide, hydrogen sulfide, and nitrogen.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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7. Properties of Natural Gases
Knowledge of PVT relationships and other physical and
chemical properties of gases is essential for solving
problems in natural gas reservoir engineering. These
properties include:
Apparent molecular weight, Ma
Specific gravity, γg
Compressibility factor, z
Density, ρg
Specific volume, v
Isothermal gas compressibility coefficient, cg
Gas formation volume factor, Bg
Gas expansion factor, Eg
Viscosity, μg
The above gas properties may be obtained from direct
laboratory measurements or by prediction from generalized
mathematical expressions.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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8. equation-of-state
For an ideal gas, the volume of molecules is
insignificant compared with the total volume
occupied by the gas.
It is also assumed that these molecules have no
attractive or repulsive forces between them, and
that all collisions of molecules are perfectly elastic.
Based on the above kinetic theory of gases, a
mathematical equation called equation-of-state can
be derived to express the relationship existing
between pressure p, volume V, and temperature T
for a given quantity of moles of gas n.
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Reservoir Fluid Properties Course:
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9. The basic properties of gases
Petroleum engineers are usually interested in the
behavior of mixtures and rarely deal with pure
component gases.
Because natural gas is a mixture of hydrocarbon
components, the overall physical and chemical
properties can be determined from the physical
properties of the individual components in the mixture
by using appropriate mixing rules.
The basic properties of gases are commonly
expressed in terms of
the apparent molecular weight, standard volume,
density, specific volume, and specific gravity.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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10. Behavior of Ideal Gases
The gas density at any
P and T:
Specific Volume
the volume occupied by
a unit mass of the gas
Apparent Molecular
Weight
Specific Gravity
Standard Volume
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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11. ideal gas behavior
Three pounds of n-butane are placed in a vessel at
120°F and 60 psia.
Calculate the volume of the gas assuming an ideal
gas behavior.
calculate the density of n-butane.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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12. ideal gas behavior
Step 1. Determine
the molecular weight of
n-butane from the Table to give:
M = 58.123
Step 2. Solve Equation for the volume of gas:
Step 3. Solve for the density by:
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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13. Ideal Gases vs. Real Gases
In dealing with gases at a very low pressure,
the ideal gas relationship is a convenient and
generally satisfactory tool.
At higher pressures,
the use of the ideal gas equation-of-state may
lead to errors as great as 500%,
as compared to errors of 2–3% at atmospheric pressure.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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14. Behavior of Real Gases
Basically, the magnitude of deviations of real gases
from the conditions of the ideal gas law increases
with increasing pressure and temperature and
varies widely with the composition of the gas.
The reason for this is that the perfect gas law was
derived under the assumption that the volume of
molecules is insignificant and that no molecular
attraction or repulsion exists between them.
Numerous equations-of-state have been developed in the
attempt to correlate the pressure-volume-temperature
variables for real gases with experimental data.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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15.
16. Gas Compressibility Factor Definition
In order to express a more exact relationship
between the variables p, V, and T,
a correction factor called the gas compressibility factor,
gas deviation factor, or simply the z-factor,
must be introduced to account for the departure of gases from
ideality.
The equation has the form of pV = znRT
Where the gas compressibility factor z is a
dimensionless quantity and is defined as the ratio
of the actual volume of n-moles of gas at T and p to
the ideal volume of the same number of moles at
the same T and p:
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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17. Corresponding States Principle for
Pure components
the critical point of a fluid is where the liquid and
vapor molar volumes become equal;
i.e., there is no distinction between the liquid and vapor
phases.
above Tc the two phases can no longer coexits.
Each compound is characterized by
its own unique (Tc), (Pc) and (Vc)
Corresponding States Principle (CSP):
All fluids behave similarly when described in terms of
their reduced temperature and pressure
Tr=T/Tc and Pr=P/Pc
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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18. Deviation from law of ideal gases
Theory of
Correspondin
g states
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Reservoir Fluid Properties Course:
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19.
20.
21. one-fluid theory (mixtures)
Generally, we apply exactly the same equations for
mixtures by treating the mixture as
a hypothetical "pure" component whose properties are
some combination of the actual pure components that
comprise it.
We call this the one-fluid theory.
To apply CSP, we use the same plot or table as pure
components but
we make the temperature and pressure dimensionless
with pseudo criticals for the hypothetical pure fluid
instead of any one set of values as scaling variables from
pure component values.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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22. mixing rules
Mixing rules form the pseudocritical of the hypothetical
pure component (the mixture) by
taking some composition average of
each component's critical properties.
Many mixing rules are commonly used and provide
more accuracy than kay’s mixing rule.
You see other mixing rules in your thermodynamics class.
Kay's mixing rules is the simplest possible,
It obtains the pseudocritical for
the hypothetical pure component.
It use a simple mole fraction average for both Tc and Pc:
𝑇 𝑝𝑐 (𝑇 𝑐,𝑚 ) = 𝑖 𝑦 𝑖 𝑇 𝑐,𝑖 ,
Ppc ( 𝑃𝑐,𝑚 ) = 𝑖 𝑦 𝑖 𝑃 𝑐,𝑖
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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23. Pseudo-Reduced Properties
Calculation (for mixtures)
Studies of the gas compressibility factors for natural
gases of various compositions have shown that
compressibility factors can be generalized with sufficient
accuracies for most engineering purposes
when they are expressed in terms of the following two
dimensionless properties:
• Pseudo-reduced pressure and
• Pseudo-reduced temperature
These dimensionless terms are defined by the following
expressions:
ppc and Tpc, do not represent the actual critical properties of
the gas mixture and are used as correlating parameters in
generating gas properties.
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Reservoir Fluid Properties Course:
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25. Standing and Katz Compressibility
Factors Chart
Based on the concept of
pseudo-reduced properties,
Standing and Katz (1942)
presented a generalized gas
compressibility factor chart.
The chart represents
compressibility factors of
sweet natural gas as a
function of ppr and Tpr.
This chart is generally
reliable for natural gas with
minor amount of
nonhydrocarbons.
It is one of the most widely
accepted correlations in the
oil and gas industry.
for higher pressure values (15 <= Ppr <= 30)
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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26.
27. Graphical method for Pseudo-Critical
Properties approximation
a graphical method for
a convenient
approximation of the
ppc and tpc of gases
when only the specific
gravity of the gas is
available.
Brown et al. (1948)
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Reservoir Fluid Properties Course:
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28. Mathematical method for PseudoCritical Properties approximation
In cases where the composition of a natural gas is
not available, the pseudo-critical properties, i.e.,
Ppc and Tpc, can be predicted solely from the
specific gravity of the gas.
Standing (1977) expressed brown et al graphical
correlation in the following mathematical forms:
Case 1: Natural Gas Systems
Case 2: Gas-Condensate Systems
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Reservoir Fluid Properties Course:
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29.
30. Nonhydrocarbon Components of
Natural Gases
Natural gases frequently contain materials other
than hydrocarbon components, such as nitrogen,
carbon dioxide, and hydrogen sulfide.
Hydrocarbon gases are classified as sweet or sour
depending on the hydrogen sulfide content.
Both sweet and sour gases may contain nitrogen, carbon
dioxide, or both.
A hydrocarbon gas is termed a sour gas if it contains one
grain of H2S per 100 cubic feet.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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31. Effect of Nonhydrocarbon
Components on the Z-Factor
The common occurrence of small percentages of
nitrogen and carbon dioxide is, in part, considered
in the correlations previously cited.
Concentrations of up to 5 percent of
these nonhydrocarbon components
will not seriously affect accuracy.
Errors in compressibility factor calculations
as large as 10 percent may occur
in higher concentrations of
nonhydrocarbon components in gas mixtures.
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Reservoir Fluid Properties Course:
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32. Nonhydrocarbon Adjustment Methods
There are two methods that were developed
to adjust the pseudo-critical properties of the gases
to account for the presence of
the nonhydrocarbon components.
Wichert-Aziz correction method
B = mole fraction of H2S in the gas mixture
ε = pseudo-critical temperature adjustment factor
• where the coefficient A is the sum of the mole fraction H2S and
CO2 in the gas mixture, or:
Carr-Kobayashi-Burrows correction method
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33. computational steps of incorporating
Nonhydrocarbon adjustment
Step 1.
Calculate the pseudo-critical properties
of the whole gas mixture
Step 2.
Calculate the adjustment factor ε
for Wichert-Aziz correction method
Step 3.
Adjust the calculated ppc and Tpc (as computed in Step 1)
Step 4.
Calculate the pseudo-reduced properties, i.e., ppr and Tpr
Step 5.
Read the compressibility factor from Figure
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Reservoir Fluid Properties Course:
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34.
35. accuracy of
the Standing-Katz factor chart
the Standing and Katz compressibility factor chart was
prepared from data on
binary mixtures of methane with propane, ethane, and
butane, and on natural gases,
thus covering a wide range in composition of hydrocarbon
mixtures containing methane.
No mixtures having molecular weights
in excess of 40 were included in preparing this plot.
Sutton (1985) evaluated the accuracy of
the Standing-Katz compressibility factor chart
using laboratory-measured
gas compositions and z factors, and found that
the chart provides satisfactory accuracy
for engineering calculations.
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Reservoir Fluid Properties Course:
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36. Correction For
High-molecular Weight Gases
However, Kay’s mixing rules, result in unsatisfactory
z-factors for high-molecular-weight reservoir gases.
The author observed that large deviations occur to
gases with high heptanes-plus concentrations.
He pointed out that Kay’s mixing rules should not be used to
determine the pseudo-critical pressure and temperature for
reservoir gases with specific gravities greater than about 0.75.
Sutton proposed that this deviation can be minimized
by utilizing
the mixing rules developed by Stewart (1959), together with
newly introduced empirical adjustment factors (FJ, EJ, and EK)
that are related to the presence of the heptane-plus fraction
in the gas mixture.
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Reservoir Fluid Properties Course:
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37. Sutton’s proposed mixing rules
Sutton’s proposed mixing rules for calculating the
pseudo-critical properties of high-molecular-weight
reservoir gases, i.e., γg > 0.75, should significantly
improve the accuracy of the calculated z-factor.
Step 1. Calculate the parameters J and K
where
J = Stewart-Burkhardt-Voo correlating parameter, °R/psia
K = Stewart-Burkhardt-Voo correlating parameter, °R/psia
yi = mole fraction of component i in the gas mixture.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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38. Sutton’s proposed mixing rules (Cont.)
Step 2. Calculate the adjustment parameters FJ, EJ,
and EK
where
yC7+ = mole fraction of the heptanes-plus component
(Tc)C7+ = critical temperature of the C7+
(pc)C7+ = critical pressure of the C7+
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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39. Sutton’s proposed mixing rules (Cont.)
Step 3. Adjust the parameters J and K by applying
the adjustment factors EJ and EK:
J′ = J − EJ and K′ = K − EK
Step 4. Calculate the adjusted pseudo-critical
temperature and pressure from the expressions:
Step 5. Having calculated the adjusted Tpc and ppc,
the regular procedure of calculating the
compressibility factor from the Standing and Katz
chart is followed.
Fall 13 H. AlamiNia
Reservoir Fluid Properties Course:
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40. 1. Ahmed, T. (2010). Reservoir engineering
handbook (Gulf Professional Publishing).
Chapter 2