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 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 provides an overview of unsteady-state flow and the diffusivity equation, which is used to model pressure changes over time in reservoirs. It discusses the assumptions and solutions of the diffusivity equation, including the Ei-function and dimensionless pressure drop solutions. The constant-terminal pressure and constant-terminal rate solutions are examined. Graphs demonstrate how pressure profiles change over different times based on these solutions. The document also explores using dimensionless variables to simplify analyses of unsteady-state flow regimes.
This document outlines topics covered in a reservoir engineering course, including:
1. PSS regimes for radial flow of single- and multi-phase fluids and the effect of well location.
2. The skin concept and using skin factors in flow equations.
3. The superposition principle for accounting for multiple wells, rate changes, boundaries, and pressure changes.
4. Applications of superposition include predicting pressure behavior for multiple wells, multi-rate wells, bounded reservoirs using image wells, and pressure changes.
5. Transient well testing provides reservoir properties through pressure response analysis.
The document discusses the concept of skin factor in wellbore flow, which is a dimensionless quantity that describes flow efficiency. A positive skin factor indicates damage that restricts flow, while a negative skin indicates flow enhancement. Skin can result from various factors like partial completion, damage near the wellbore, hydraulic fracturing, or deviation of the well from vertical. Equations are provided to calculate the pressure drop and flow efficiency based on the skin factor. The total skin is the sum of individual skin components from different sources like damage, completion, deviation etc.
production optimization nowadays is a vital thing to capture for every gas field to get proper production rate. That's they need proper way to optimize there production. Here I have discussed about the process of production optimization using prosper softer from petroleum expert.
This document provides an overview of reservoir engineering concepts for predicting vertical oil well performance, including productivity index, inflow performance relationship, and methods for modeling these relationships. It discusses key topics like:
- Defining and measuring productivity index using stabilized well test data
- How productivity index, inflow performance relationship, and well flow rates relate under pseudosteady state conditions
- Factors influencing productivity index like fluid properties and relative permeability
- Empirical methods like Vogel's method for generating inflow performance curves over the life of depleting reservoirs
The document is from a course on reservoir engineering concepts for vertical wells, with the goal of teaching practical equations to model well performance and factors governing fluid flow.
Skin factor is a dimensionless parameter that quantifies the formation damage around the wellbore. it also can be negative (which indicates improvement in flow) OR positive (which means formation damage exists). Positive skin can lead to severe well production issues and thus reducing the well revenue
This document provides an overview of reservoir engineering concepts related to gas well performance. It discusses different methods for approximating inflow performance relationships (IPRs) for gas wells under various flow regimes, including the pseudosteady state, and accounting for laminar versus turbulent flow. Empirical models are presented for calculating gas flow rates based on reservoir properties, fluid properties, and operating pressures. The document also examines pressure regions and appropriate approaches for each, such as using real gas pseudopressure or a pressure-squared method at low pressures.
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 provides an overview of unsteady-state flow and the diffusivity equation, which is used to model pressure changes over time in reservoirs. It discusses the assumptions and solutions of the diffusivity equation, including the Ei-function and dimensionless pressure drop solutions. The constant-terminal pressure and constant-terminal rate solutions are examined. Graphs demonstrate how pressure profiles change over different times based on these solutions. The document also explores using dimensionless variables to simplify analyses of unsteady-state flow regimes.
This document outlines topics covered in a reservoir engineering course, including:
1. PSS regimes for radial flow of single- and multi-phase fluids and the effect of well location.
2. The skin concept and using skin factors in flow equations.
3. The superposition principle for accounting for multiple wells, rate changes, boundaries, and pressure changes.
4. Applications of superposition include predicting pressure behavior for multiple wells, multi-rate wells, bounded reservoirs using image wells, and pressure changes.
5. Transient well testing provides reservoir properties through pressure response analysis.
The document discusses the concept of skin factor in wellbore flow, which is a dimensionless quantity that describes flow efficiency. A positive skin factor indicates damage that restricts flow, while a negative skin indicates flow enhancement. Skin can result from various factors like partial completion, damage near the wellbore, hydraulic fracturing, or deviation of the well from vertical. Equations are provided to calculate the pressure drop and flow efficiency based on the skin factor. The total skin is the sum of individual skin components from different sources like damage, completion, deviation etc.
production optimization nowadays is a vital thing to capture for every gas field to get proper production rate. That's they need proper way to optimize there production. Here I have discussed about the process of production optimization using prosper softer from petroleum expert.
This document provides an overview of reservoir engineering concepts for predicting vertical oil well performance, including productivity index, inflow performance relationship, and methods for modeling these relationships. It discusses key topics like:
- Defining and measuring productivity index using stabilized well test data
- How productivity index, inflow performance relationship, and well flow rates relate under pseudosteady state conditions
- Factors influencing productivity index like fluid properties and relative permeability
- Empirical methods like Vogel's method for generating inflow performance curves over the life of depleting reservoirs
The document is from a course on reservoir engineering concepts for vertical wells, with the goal of teaching practical equations to model well performance and factors governing fluid flow.
Skin factor is a dimensionless parameter that quantifies the formation damage around the wellbore. it also can be negative (which indicates improvement in flow) OR positive (which means formation damage exists). Positive skin can lead to severe well production issues and thus reducing the well revenue
This document provides an overview of reservoir engineering concepts related to gas well performance. It discusses different methods for approximating inflow performance relationships (IPRs) for gas wells under various flow regimes, including the pseudosteady state, and accounting for laminar versus turbulent flow. Empirical models are presented for calculating gas flow rates based on reservoir properties, fluid properties, and operating pressures. The document also examines pressure regions and appropriate approaches for each, such as using real gas pseudopressure or a pressure-squared method at low pressures.
1. The document discusses various mathematical models for estimating water influx into oil and gas reservoirs, including the Pot aquifer model, Schilthuis' steady-state model, and Hurst's modified steady-state model. It describes the assumptions and equations of each model.
2. Determining water influx is challenging due to uncertainties about aquifer properties which are rarely known with accuracy. Models require historical reservoir data to evaluate constants representing aquifer parameters.
3. Common water influx models include Pot aquifer, Schilthuis' steady-state, Hurst's modified steady-state, van Everdingen-Hurst unsteady-state, and others. The document provides details on implementing some of these models
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 provides an overview of key topics in reservoir engineering 1, including Darcy's law and its applications to linear and radial flow models. It covers reservoir characteristics like fluid types, flow regimes, geometries, and properties. The steady-state flow regime is examined for linear and radial flow of incompressible, slightly compressible, and compressible fluids. Other topics include tilted reservoirs, fluid potential, multiphase flow, and pressure disturbances. Mathematical formulations are presented for unsteady-state and transient fluid flow analysis.
This document describes various methods for generating and predicting inflow performance relationships (IPRs), including Vogel's method, Wiggins' method, and Standing's method. Vogel's method uses dimensionless parameters and curve fitting to develop IPR curves from reservoir simulation data. Wiggins' method similarly develops generalized IPR correlations through reservoir modeling. Standing's method extends Vogel's approach by introducing the zero-drawdown productivity index to allow prediction of future IPRs based on declining reservoir pressure.
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 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
1) Three types of fluid flow can occur in a reservoir: steady-state, semi-steady state, and unsteady-state flow.
2) Steady-state flow very rarely occurs and requires a strong pressure maintenance mechanism like an aquifer to replenish pressure changes from production.
3) Semi-steady state is the dominant type, where pressure declines uniformly throughout the reservoir as the boundaries have been encountered.
4) Unsteady-state flow occurs early in a well's life before boundaries are felt, and the reservoir acts infinitely. The correct flow equations depend on identifying the type of flow.
Bullheading is a common non-circulating method for killing live wells prior to workovers. It involves pumping kill fluid into the tubing to displace produced fluids back into the formation. A bullheading schedule is generated using formation pressure, desired overbalance, fracture pressure, tubing specifications, and pump data to safely control pumping pressures within the initial and final maximum pressures. The schedule provides checkpoints to monitor pumping pressure and volume throughout the operation. Special attention should be paid to any increases in casing pressure which could indicate downhole issues.
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.
Production decline analysis is a traditional means of identifying well production problems and predicting well performance and life based on real production data. It uses empirical decline models that have little fundamental justifications. These models include
•
Exponential decline (constant fractional decline)
•
Harmonic decline, and
•
Hyperbolic decline.
Reservoir engineers cannot capture full value from waterflood projects on their own. Cross-functional participation from earth sciences, production, drilling, completions, and facility engineering, and operational groups is required to get full value from waterfloods. Waterflood design and operational case histories of cross-functional collaboration are provided that have improved life cycle costs and increased recovery for onshore and offshore waterfloods. The role that water quality, surveillance, reservoir processing rates, and layered reservoir management has on waterflood oil recovery and life cycle costs will be clarified. Techniques to get better performance out of your waterflood will be shared.
Complete Casing Design with types of casing, casing properties, casing functions, design criteria and properties used for designing and one numerical problem
The document discusses reservoir-aquifer systems and water drive mechanisms in oil and gas reservoirs. It defines key terms like aquifers, water encroachment, and active water drive. It also classifies reservoir-aquifer systems based on factors like the degree of pressure maintenance, flow regimes, outer boundary conditions, and flow geometries. The document provides diagrams to illustrate different types of flow geometries in reservoir-aquifer systems, including edge-water drive and bottom-water drive. It also discusses clues that can indicate the presence of natural water drive in a reservoir.
This document discusses various methods for controlling water and gas coning in oil wells, including dual completions, chemical treatments, and downhole water sink (DWS) technology. DWS involves installing a second completion below the oil-water contact to drain and produce water, preventing it from coning into the main oil zone. It has been shown to effectively control coning through creating a hysteresis effect. While simple to implement, DWS may not be economical for low-producing wells. Overall, DWS appears to be one of the most effective methods for retarding unwanted water and gas influx compared to alternatives like producing below critical rates or using polymers that can damage the 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.
1. The document describes several mathematical models for calculating water influx into oil reservoirs from surrounding aquifers, including the van Everdingen-Hurst model. This model uses the diffusivity equation to relate dimensionless water influx to dimensionless time and radius, allowing generalized calculations. It assumes radial flow into reservoirs from aquifers with uniform properties.
2. The document outlines the computational steps for calculating cumulative water influx at successive time intervals using the van Everdingen-Hurst model. This involves determining the contribution to water influx from each discrete pressure drop using superposition.
3. Modifications to the van Everdingen-Hurst model include accounting for non-circular reservoir boundaries and approximating pressure
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.
This document discusses the key calculations involved in a kill sheet for plugging and abandoning an oil well. It explains that a kill sheet is used to determine well parameters like volume, strokes, time, mud weights, and circulating pressures. It provides step-by-step worked examples of calculating strokes, times, kill mud weight, initial and final circulating pressures, and a step down chart. The calculations allow operators to safely pump heavy kill mud into the well to displace the drilling fluid before cementing and abandoning the well.
This document outlines the key concepts in reservoir engineering. It discusses reservoir characteristics including fluid types, flow regimes, and geometries. It then covers steady-state and unsteady-state flow, defining transient flow as the period where the reservoir boundary has no effect. The document derives the diffusivity equation from continuity, transport, and compressibility equations. It discusses the assumptions and solutions of the diffusivity equation, including constant-terminal pressure and rate solutions.
This document provides an overview of a reservoir engineering course focused on Darcy's Law and permeability. It covers key topics like laboratory analysis of rock properties including porosity, saturation and permeability. It also discusses linear and radial flow models based on Darcy's Law and techniques for determining permeability in the laboratory and averaging permeabilities for heterogeneous reservoirs. The document emphasizes that permeability is an important property that controls fluid flow in reservoirs and was first mathematically defined by Henry Darcy. It provides the equations for linear and radial flow based on Darcy's Law.
This document outlines various methods for predicting the inflow performance relationship (IPR) for vertical and horizontal oil wells. It discusses Vogel's, Wiggins', Standing's, and Fetkovich's methods for predicting the IPR and future IPR of vertical wells based on reservoir pressure decline. It also covers horizontal well advantages, drainage area calculations, and approaches for modeling steady-state and pseudosteady-state flow performance of horizontal wells. The document provides step-by-step explanations of each IPR prediction technique.
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.
1. The document discusses various mathematical models for estimating water influx into oil and gas reservoirs, including the Pot aquifer model, Schilthuis' steady-state model, and Hurst's modified steady-state model. It describes the assumptions and equations of each model.
2. Determining water influx is challenging due to uncertainties about aquifer properties which are rarely known with accuracy. Models require historical reservoir data to evaluate constants representing aquifer parameters.
3. Common water influx models include Pot aquifer, Schilthuis' steady-state, Hurst's modified steady-state, van Everdingen-Hurst unsteady-state, and others. The document provides details on implementing some of these models
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 provides an overview of key topics in reservoir engineering 1, including Darcy's law and its applications to linear and radial flow models. It covers reservoir characteristics like fluid types, flow regimes, geometries, and properties. The steady-state flow regime is examined for linear and radial flow of incompressible, slightly compressible, and compressible fluids. Other topics include tilted reservoirs, fluid potential, multiphase flow, and pressure disturbances. Mathematical formulations are presented for unsteady-state and transient fluid flow analysis.
This document describes various methods for generating and predicting inflow performance relationships (IPRs), including Vogel's method, Wiggins' method, and Standing's method. Vogel's method uses dimensionless parameters and curve fitting to develop IPR curves from reservoir simulation data. Wiggins' method similarly develops generalized IPR correlations through reservoir modeling. Standing's method extends Vogel's approach by introducing the zero-drawdown productivity index to allow prediction of future IPRs based on declining reservoir pressure.
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 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
1) Three types of fluid flow can occur in a reservoir: steady-state, semi-steady state, and unsteady-state flow.
2) Steady-state flow very rarely occurs and requires a strong pressure maintenance mechanism like an aquifer to replenish pressure changes from production.
3) Semi-steady state is the dominant type, where pressure declines uniformly throughout the reservoir as the boundaries have been encountered.
4) Unsteady-state flow occurs early in a well's life before boundaries are felt, and the reservoir acts infinitely. The correct flow equations depend on identifying the type of flow.
Bullheading is a common non-circulating method for killing live wells prior to workovers. It involves pumping kill fluid into the tubing to displace produced fluids back into the formation. A bullheading schedule is generated using formation pressure, desired overbalance, fracture pressure, tubing specifications, and pump data to safely control pumping pressures within the initial and final maximum pressures. The schedule provides checkpoints to monitor pumping pressure and volume throughout the operation. Special attention should be paid to any increases in casing pressure which could indicate downhole issues.
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.
Production decline analysis is a traditional means of identifying well production problems and predicting well performance and life based on real production data. It uses empirical decline models that have little fundamental justifications. These models include
•
Exponential decline (constant fractional decline)
•
Harmonic decline, and
•
Hyperbolic decline.
Reservoir engineers cannot capture full value from waterflood projects on their own. Cross-functional participation from earth sciences, production, drilling, completions, and facility engineering, and operational groups is required to get full value from waterfloods. Waterflood design and operational case histories of cross-functional collaboration are provided that have improved life cycle costs and increased recovery for onshore and offshore waterfloods. The role that water quality, surveillance, reservoir processing rates, and layered reservoir management has on waterflood oil recovery and life cycle costs will be clarified. Techniques to get better performance out of your waterflood will be shared.
Complete Casing Design with types of casing, casing properties, casing functions, design criteria and properties used for designing and one numerical problem
The document discusses reservoir-aquifer systems and water drive mechanisms in oil and gas reservoirs. It defines key terms like aquifers, water encroachment, and active water drive. It also classifies reservoir-aquifer systems based on factors like the degree of pressure maintenance, flow regimes, outer boundary conditions, and flow geometries. The document provides diagrams to illustrate different types of flow geometries in reservoir-aquifer systems, including edge-water drive and bottom-water drive. It also discusses clues that can indicate the presence of natural water drive in a reservoir.
This document discusses various methods for controlling water and gas coning in oil wells, including dual completions, chemical treatments, and downhole water sink (DWS) technology. DWS involves installing a second completion below the oil-water contact to drain and produce water, preventing it from coning into the main oil zone. It has been shown to effectively control coning through creating a hysteresis effect. While simple to implement, DWS may not be economical for low-producing wells. Overall, DWS appears to be one of the most effective methods for retarding unwanted water and gas influx compared to alternatives like producing below critical rates or using polymers that can damage the 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.
1. The document describes several mathematical models for calculating water influx into oil reservoirs from surrounding aquifers, including the van Everdingen-Hurst model. This model uses the diffusivity equation to relate dimensionless water influx to dimensionless time and radius, allowing generalized calculations. It assumes radial flow into reservoirs from aquifers with uniform properties.
2. The document outlines the computational steps for calculating cumulative water influx at successive time intervals using the van Everdingen-Hurst model. This involves determining the contribution to water influx from each discrete pressure drop using superposition.
3. Modifications to the van Everdingen-Hurst model include accounting for non-circular reservoir boundaries and approximating pressure
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.
This document discusses the key calculations involved in a kill sheet for plugging and abandoning an oil well. It explains that a kill sheet is used to determine well parameters like volume, strokes, time, mud weights, and circulating pressures. It provides step-by-step worked examples of calculating strokes, times, kill mud weight, initial and final circulating pressures, and a step down chart. The calculations allow operators to safely pump heavy kill mud into the well to displace the drilling fluid before cementing and abandoning the well.
This document outlines the key concepts in reservoir engineering. It discusses reservoir characteristics including fluid types, flow regimes, and geometries. It then covers steady-state and unsteady-state flow, defining transient flow as the period where the reservoir boundary has no effect. The document derives the diffusivity equation from continuity, transport, and compressibility equations. It discusses the assumptions and solutions of the diffusivity equation, including constant-terminal pressure and rate solutions.
This document provides an overview of a reservoir engineering course focused on Darcy's Law and permeability. It covers key topics like laboratory analysis of rock properties including porosity, saturation and permeability. It also discusses linear and radial flow models based on Darcy's Law and techniques for determining permeability in the laboratory and averaging permeabilities for heterogeneous reservoirs. The document emphasizes that permeability is an important property that controls fluid flow in reservoirs and was first mathematically defined by Henry Darcy. It provides the equations for linear and radial flow based on Darcy's Law.
This document outlines various methods for predicting the inflow performance relationship (IPR) for vertical and horizontal oil wells. It discusses Vogel's, Wiggins', Standing's, and Fetkovich's methods for predicting the IPR and future IPR of vertical wells based on reservoir pressure decline. It also covers horizontal well advantages, drainage area calculations, and approaches for modeling steady-state and pseudosteady-state flow performance of horizontal wells. The document provides step-by-step explanations of each IPR prediction technique.
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 a reservoir engineering course focused on fundamental rock properties. It discusses key topics like porosity, saturation, wettability, capillary pressure, and how they are determined through laboratory core analysis. Porosity refers to the pore space available to hold fluids and is classified as absolute or effective porosity. Saturation represents the fraction of pore space occupied by a fluid. Capillary pressure describes the pressure differential between immiscible fluids based on interface curvature. Laboratory tests on core samples are used to characterize these important rock properties.
This document provides an overview of key concepts in reservoir engineering related to waterflooding, including:
1) Fractional flow curves and how injection parameters like viscosity, formation dip, and rate affect the water cut. Higher oil viscosity or water viscosity results in a higher/lower water cut respectively. Uphill injection improves displacement efficiency.
2) The frontal advance equation describes how water saturation progresses through a reservoir based on the slope of the fractional flow curve and injection rate.
3) Equations show the relationships between reservoir water cut, surface water cut, and water-oil ratios both at reservoir and surface conditions.
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 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 document provides an overview of reservoir engineering concepts related to waterflooding projects for oil recovery. It discusses primary, secondary, and tertiary recovery categories. For waterflooding projects specifically, it outlines key factors to consider like reservoir geometry, fluid properties, depth, lithology, fluid saturations, uniformity, and natural driving mechanisms. It provides details on evaluating these factors and their implications for project suitability and design.
This document provides an overview of reservoir engineering concepts related to primary recovery mechanisms, aquifers, and the gravity drainage drive mechanism. It discusses topics like water drive characteristics including reservoir pressure trends, water production patterns, and ultimate oil recovery percentages. Key points covered include how aquifer size and geometry can impact reservoir performance and how gravity segregation of reservoir fluids over time leads to gas, oil, and water occupying distinct horizontal layers.
This document provides an overview of a reservoir engineering course covering topics like:
- PSS and skin concepts for radial flow of single- and multi-phase fluids
- Turbulent versus laminar flow and models for turbulent/non-Darcy flow
- The concept of superposition and its applications, including effects of multiple wells, rate changes, boundaries, and pressure changes
- Transient well testing methods and the information they provide about a reservoir's properties
The document discusses reservoir engineering concepts including Welge analysis and breakthrough determination. It describes how to construct fractional flow curves and use them with Welge analysis to determine water saturation profiles over time, the time to breakthrough, average water saturation, and cumulative water injection. The key steps are: 1) constructing the fractional flow curve; 2) drawing a tangent line to determine water saturation at the front and water cut; 3) using equations to calculate distance traveled and develop saturation profiles. Breakthrough occurs when the front reaches the production well, determined using pore volume and well spacing. Average saturation is found where the tangent intersects a water cut of 1.
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 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 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.
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 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 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 summarizes key concepts from a reservoir engineering course, including pseudosteady-state (PSS) flow regimes for radial flow of slightly compressible (SC) and compressible (C) fluids. It discusses how the PSS flow condition is reached after transient flow, and how average reservoir pressure changes at a constant rate in PSS. Equations are provided for calculating flow rates of SC and C fluids in PSS, along with approximations that account for skin effect and non-ideal assumptions.
The document covers reservoir engineering concepts including solutions to the diffusivity equation for radial flow of single-phase and compressible fluids. It discusses the pD and Ei-function solutions, and presents the unified steady-state flow regime equations for radial flow of single-phase and compressible fluids using the pD-function, m(p)-function, and pressure-squared approximations. It also covers the pseudo-steady state flow regime and relationships between pressure functions.
This document outlines key concepts in reservoir engineering related to fluid flow regimes including unsteady-state flow, pseudosteady-state flow, and the use of skin and shape factors to account for non-ideal reservoir conditions. Specific topics covered include solutions to the diffusivity equation, radial flow equations for slightly compressible and compressible fluids, and modifications to account for wellbore skin effects and different flow geometries. The document provides equations and examples for analyzing fluid flow and pressure distribution during different flow regimes.
This paper presents the further developments and working principle of the speed-variable switched differential pump (SvSDP) concept proposed, designed and produced in [1]. The SvSDP system is designed to remove the throttling losses associated with typical valve driven control (VDC) systems. The hydraulic and mechanical system is modelled and linearised. The linearisation point is studied to provide an usable basis for controller design. It is proposed, in this paper, to model the converter and motor using a black box approach, where designed and informative input sequences are used to estimate the mathematical behaviour of the electrical drive based on the equivalent output data. The complete non linear model is verified against available trajectory data from the physical system, obtained from [1]. The linear model is analysed through a relative gain array (RGA) analysis to map the input output couplings present in the system. The results show that the system includes heavy cross-couplings. Results presented in [1] indicate, that it is possible to utilise a input output compensated decoupling to redefine the MIMO system into multiple SISO systems. The SvSDP concept is over-determined in relation to the amount of control inputs compared to possible outputs.
It is proposed in [1] to introduce two new input states and two new output states. The decoupling approach has been investigated in this paper. The decoupling results provided a basis of using decentralised control. The linear control strategies are designed independently based on the notion of decoupling. The first controller is related to the level flow, designed to maintain a desired minimum pressure level. The second load flow controller is related to the cylinder motion. The controller results indicate, that it is possible to achieve a good dynamic tracking performance with an error of maximum 0.5 mm for a given position trajectory.
This paper is also considering the energy consumption issues stated in [1], where two conceptual solutions are proposed, to solve the power loss associated with holding a load at a constant cylinder position. This paper is written as the product of an appendix report describing the whole project.
This document provides an overview of steady state radial flow in reservoirs. It discusses steady state flow of incompressible, slightly compressible, and compressible fluids. For incompressible fluids, Darcy's law is used to calculate flow rates. For compressible fluids, the real gas potential and pseudopressure are introduced to account for compressibility. Flow rates can be expressed in terms of average reservoir pressure or approximated using the p-squared method. The document also covers multiphase flow, flow ratios of water-oil and gas-oil, and pressure disturbance for a shut-in well.
This document presents SEA, an experimental testing environment for electrohydraulic actuators. SEA allows for precise measurement of important actuator variables to enable comprehensive static and dynamic characterization. It includes a hydraulic pump and pipelines, configurable loads, an instrumented manifold for measurements, and a DAQ system. Experimental results from characterizing an aerospace actuator using SEA are provided, including static calibration, transient response testing showing high pressure and flow demands, and system identification to develop an input-output mathematical model. SEA provides an effective environment for full experimental characterization of electrohydraulic actuators.
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.
Gas lift system is optimized by use of PVT data combined with fluid and multiphase flow correlations. The aim of project is to develop a generalized program that eliminate the use of synthetic Gradient curves and sensitivity of system with respect to each parameter can be analyzed easily. The project is mainly based on two pressure gradient models; one is single phase flow of compressible fluids (gas) and second is multi-phase correlation developed by Hagedorn and Brown3 including Griffith correction4 of bubble flow particularly for vertical wellbores. Different but appropriate PVT correlations are adopted to suit the condition. The project is divided into two parts, first is developing single Gas lift diagram and second is multiple Gas lift diagrams which facilitate to derive Equilibrium curve, usually use to have idea of unloading valves at different depths with varying flowrates
A practical method to predict performance curves of centrifugal water pumpsJohn Barry
This document presents a numerical model for predicting the performance curves of centrifugal water pumps. The model requires easily obtainable pump geometrical data and empirical coefficients. It was developed to provide a fast approximation of pump characteristic curves, including pressure head, volumetric efficiency, and power required. The model was validated by comparing predictions to experimental data from 30 pumps tested on a pump test rig. On average, the model predicted head within 5.16% error, power within 10.6% error, and efficiency within 7.3% error. The results indicate the method provides a satisfactory approximation of pump performance curves.
1. The document analyzes and compares the energy efficiency of three variants of an electrohydraulic closed-loop control system for driving electric generators using wave energy.
2. It calculates the hydraulic losses at maximum and minimum flow rates for each variant, finding the highest losses of 5.4 kW for Variant 1 and lowest of 1.6 kW for Variant 2.
3. An analysis of energy efficiency shows Variant 2 is the most efficient at 93.6%, followed closely by Variant 3 at 93.3%, while Variant 1 has the lowest efficiency at 78.4%.
This document summarizes experimental work characterizing two-phase flow in centrifugal pumps. Small pressure sensors were used to measure pressure distributions in an impeller, diffuser, and volute under varying air-water flow conditions. High-speed photography was also used. Analytical models were developed to predict single- and two-phase pressure distributions, and compared to test data. Previous related pump test programs are also summarized. Equations for analyzing single-phase pump performance and predicting pressure rises in the suction, impeller, diffuser, and volute are provided.
International Journal of Engineering Research and DevelopmentIJERD Editor
Electrical, Electronics and Computer Engineering,
Information Engineering and Technology,
Mechanical, Industrial and Manufacturing Engineering,
Automation and Mechatronics Engineering,
Material and Chemical Engineering,
Civil and Architecture Engineering,
Biotechnology and Bio Engineering,
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Petroleum and Mining Engineering,
Marine and Agriculture engineering,
Aerospace Engineering.
This document describes how to develop a Microsoft Excel program to aid in sizing and selecting centrifugal pumps for process pumping needs. It outlines the basic model, applicable equations including Bernoulli's equation and Darcy's equation for pressure loss. It also discusses parameters like Reynolds number, friction factor, pipe roughness, and provides the Colebrook equation for calculating friction factor. The document recommends using Excel's Solver tool to iteratively solve the Colebrook equation by setting the friction factor as the target cell and constraints.
Flow Control in a Diffuser at Transonic ConditionsJeremy Gartner
This document discusses an experimental study of flow control techniques in a transonic diffuser. A new diffuser design was created with an upper ramp and straight floor to decouple the secondary flow structures from separation. Different flow control actuators including steady and unsteady jets were tested at the ramp. The actuators were able to delay separation on the ramp and increase pressure recovery by up to 9.7% compared to the baseline case without flow control. Sweeping and pulsed jet arrays performed better than a two-dimensional jet when all were operated at their maximum mass flow ratios. The results provide insights into controlling flows in short inlet ducts used on aircraft.
Numerical Investigation of Flow Field Behaviour and Pressure Fluctuations wit...Mustansiriyah University
this present work, CFD numerical method is applied to analyses the flow field in
an axial flow pump qualitative and quantitative analyses. Qualitative analysis for these
parameters comprise static pressure variations, dynamic pressure variations, velocity magnitude,
turbulent kinetic energy, shear stress. Quantitative analysis including the pressure fluctuations in
frequency domain analysis under different operation conditions. Also, sliding mesh method and
turbulence model type k- epsilon are used. Various monitoring points are stalled in order to
analyses pressure fluctuation mechanism in the impeller blade. The numerical results revealed
that the flow field for pressure and velocity are increase start from the suction side of the pump
to discharge side. Also, the results found that the high pressure occurs at the discharge side
along the axial direction of the impeller. The maximum value of pressure fluctuations is
occurred at tip blade region due to high interaction flow at this particular area. Moreover, the
pressure decreases as flow rate in the pump increases. Additionally, the results shown that the
pressure fluctuations have four peaks and four valleys the similar impeller blades number.
Furthermore, there are different positive and negative pressure regions, the negative pressure
area occurs due to lower pressure zone at inlet impeller area and hence which can lead to cause
occurrence of cavitation in this specific area. The current numerical demonstration results can
help the researches for further axial flow pump design.
Modeling And Simulation Swash Plate Pump Response Characteristics in Load Sen...IJMERJOURNAL
ABSTRACT: Fluid Power is widely employed in applications required high loads such as tractors, cranes, and airplanes. In load sensing hydraulic systems, loads are controlled by adjusting a pump-valve arrangement. In this paper, the swash plate pump hydraulic characteristics will be determined, the pump and its fluid gains will be derived to obtain the pump overall transfer function. Firstly, the swash plate pump mechanism is analyzed and its dynamic model is constructed; the pump pressure and flow rate are plotted and the possible improvement is introduced. The load sensing unit parameters such as orifice width, orifice area, maximum passage area, and piston area at X and Y will be examined to identify their influence on the pump characteristics; and the optimum parameters will be introduced. All results are developed and simulated numerically.
This document provides an overview of reservoir engineering concepts related to analyzing fluid flow in reservoirs, including:
1. It introduces dimensionless variables like dimensionless pressure (pD) that are used to simplify solutions to the diffusivity equation governing fluid flow. pD solutions are presented for both infinite-acting and finite radial reservoirs.
2. Methods for solving the diffusivity equation for compressible (gas) fluids are described, including exact (m(p)-solution) and approximate (pressure-squared, pressure) methods.
3. The dimensionless forms of these solutions - like dimensionless real gas pseudopressure drop (ψD) - are also introduced and their calculation methods explained.
This document discusses using the derivative of pressure with respect to time to analyze well test data. It proposes a differentiation algorithm and shows through field examples how the pressure derivative method simplifies interpretation by making it easier and more accurate. The method considers the full pressure response rather than isolating regions, and emphasizes the important infinite radial flow regime through use of the logarithmic derivative. It provides a description of reservoir flow behavior that matches type curves and is consistent with conventional straight-line analysis.
1. The document presents a pressure transient analysis method for a reservoir with an internal circular boundary, such as a gas cap.
2. The problem is modeled using the Laplace transform solution of the diffusivity equation with boundary conditions. This allows developing a generalized type curve solution.
3. A new generalized type curve is presented, which allows estimating the permeability of the reservoir section within the boundary and the transient time to reach the boundary through type curve matching, without using the double straight line technique.
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.
Walmart Business+ and Spark Good for Nonprofits.pdfTechSoup
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The webinar may also give some examples on how nonprofits can best leverage Walmart Business+.
The event will cover the following::
Walmart Business + (https://business.walmart.com/plus) is a new shopping experience for nonprofits, schools, and local business customers that connects an exclusive online shopping experience to stores. Benefits include free delivery and shipping, a 'Spend Analytics” feature, special discounts, deals and tax-exempt shopping.
Special TechSoup offer for a free 180 days membership, and up to $150 in discounts on eligible orders.
Spark Good (walmart.com/sparkgood) is a charitable platform that enables nonprofits to receive donations directly from customers and associates.
Answers about how you can do more with Walmart!"
This document provides an overview of wound healing, its functions, stages, mechanisms, factors affecting it, and complications.
A wound is a break in the integrity of the skin or tissues, which may be associated with disruption of the structure and function.
Healing is the body’s response to injury in an attempt to restore normal structure and functions.
Healing can occur in two ways: Regeneration and Repair
There are 4 phases of wound healing: hemostasis, inflammation, proliferation, and remodeling. This document also describes the mechanism of wound healing. Factors that affect healing include infection, uncontrolled diabetes, poor nutrition, age, anemia, the presence of foreign bodies, etc.
Complications of wound healing like infection, hyperpigmentation of scar, contractures, and keloid formation.
Leveraging Generative AI to Drive Nonprofit InnovationTechSoup
In this webinar, participants learned how to utilize Generative AI to streamline operations and elevate member engagement. Amazon Web Service experts provided a customer specific use cases and dived into low/no-code tools that are quick and easy to deploy through Amazon Web Service (AWS.)
Temple of Asclepius in Thrace. Excavation resultsKrassimira Luka
The temple and the sanctuary around were dedicated to Asklepios Zmidrenus. This name has been known since 1875 when an inscription dedicated to him was discovered in Rome. The inscription is dated in 227 AD and was left by soldiers originating from the city of Philippopolis (modern Plovdiv).
Chapter wise All Notes of First year Basic Civil Engineering.pptxDenish Jangid
Chapter wise All Notes of First year Basic Civil Engineering
Syllabus
Chapter-1
Introduction to objective, scope and outcome the subject
Chapter 2
Introduction: Scope and Specialization of Civil Engineering, Role of civil Engineer in Society, Impact of infrastructural development on economy of country.
Chapter 3
Surveying: Object Principles & Types of Surveying; Site Plans, Plans & Maps; Scales & Unit of different Measurements.
Linear Measurements: Instruments used. Linear Measurement by Tape, Ranging out Survey Lines and overcoming Obstructions; Measurements on sloping ground; Tape corrections, conventional symbols. Angular Measurements: Instruments used; Introduction to Compass Surveying, Bearings and Longitude & Latitude of a Line, Introduction to total station.
Levelling: Instrument used Object of levelling, Methods of levelling in brief, and Contour maps.
Chapter 4
Buildings: Selection of site for Buildings, Layout of Building Plan, Types of buildings, Plinth area, carpet area, floor space index, Introduction to building byelaws, concept of sun light & ventilation. Components of Buildings & their functions, Basic concept of R.C.C., Introduction to types of foundation
Chapter 5
Transportation: Introduction to Transportation Engineering; Traffic and Road Safety: Types and Characteristics of Various Modes of Transportation; Various Road Traffic Signs, Causes of Accidents and Road Safety Measures.
Chapter 6
Environmental Engineering: Environmental Pollution, Environmental Acts and Regulations, Functional Concepts of Ecology, Basics of Species, Biodiversity, Ecosystem, Hydrological Cycle; Chemical Cycles: Carbon, Nitrogen & Phosphorus; Energy Flow in Ecosystems.
Water Pollution: Water Quality standards, Introduction to Treatment & Disposal of Waste Water. Reuse and Saving of Water, Rain Water Harvesting. Solid Waste Management: Classification of Solid Waste, Collection, Transportation and Disposal of Solid. Recycling of Solid Waste: Energy Recovery, Sanitary Landfill, On-Site Sanitation. Air & Noise Pollution: Primary and Secondary air pollutants, Harmful effects of Air Pollution, Control of Air Pollution. . Noise Pollution Harmful Effects of noise pollution, control of noise pollution, Global warming & Climate Change, Ozone depletion, Greenhouse effect
Text Books:
1. Palancharmy, Basic Civil Engineering, McGraw Hill publishers.
2. Satheesh Gopi, Basic Civil Engineering, Pearson Publishers.
3. Ketki Rangwala Dalal, Essentials of Civil Engineering, Charotar Publishing House.
4. BCP, Surveying volume 1
2. 1. Vertical Gas Well Performance
2. Pressure Application Regions
3. Turbulent Flow in Gas Wells
A. Simplified Treatment Approach
B. Laminar-Inertial-Turbulent (LIT) Approach (Cases A.
& B.)
3. 1. Turbulent Flow in Gas Wells: LIT Approach
(Case C)
2. Comparison of Different IPR Calculation
Methods
3. Future IPR for Gas Wells
4. Horizontal Gas Well Performance
5. Primary Recovery Mechanisms
6. Basic Driving Mechanisms
4.
5. Case C.
Pseudopressure Quadratic Approach
Pseudopressure Equation can be written as:
Where
The term (a2 Qg) represents the pseudopressure
drop due to laminar flow while the term (b2 Qg2)
accounts for the pseudopressure drop due to
inertial-turbulent flow effects.
The Equation can be linearized by dividing both
sides of the equation by Qg to yield:
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6. Case C. Graph of Real Gas PseudoPressure Data
The above
expression
suggests that a
plot of versus
Qg on a
Cartesian scale
should yield a
straight line
with a slope of
b2 and
intercept of a2
as shown in
Figure.
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7. Case C. Gas Flow Rate Calculation
Given the values of a2 and b2, the gas flow rate at
any pwf is calculated from:
It should be pointed out that the pseudopressure
approach is more rigorous than either the pressuresquared or pressure-approximation method and is
applicable to all ranges of pressure.
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8.
9. The Back-Pressure Test
Rawlins and
Schellhardt (1936)
proposed a method for
testing gas wells by
gauging the ability of
the well to flow against
various back pressures.
This type of flow test is
commonly referred to
as the conventional
deliverability test.
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10. IPR for Different Methods
Figure
compares
graphically
the
performance
of each
method with
that of ψapproach.
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11. IPR for All Methods (Cont.)
Since the pseudo-pressure analysis is considered more
accurate and rigorous than the other three methods,
the accuracy of each of the methods in predicting the
IPR data is compared with that of the ψ-approach.
Results indicate that the pressure-squared equation
generated the IPR data with an absolute average error
of 5.4% as compared with 6% and 11% for the backpressure equation and the pressure approximation
method, respectively.
It should be noted that the pressure-approximation method is
limited to applications for pressures greater than 3000 psi.
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12.
13. Future
Inflow Performance Relationships
Once a well has been tested and the appropriate
deliverability or inflow performance equation
established,
It is essential to predict the IPR data as a function of
average reservoir pressure.
The gas viscosity μg and gas compressibility z-factor
are considered the parameters that are subject to
the greatest change as reservoir pressure p–r
changes.
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14. Future IPR Methodology
Assume that the current average reservoir pressure is
p–r, with gas viscosity of μg1 and a compressibility
factor of z1. At a selected future average reservoir
pressure p–r2, μg2 and z2 represent the corresponding
gas properties.
To approximate the effect of reservoir pressure
changes, i.e. from p–r1 to p–r2, on the coefficients of
the deliverability equation, the following methodology
is recommended:
Back-Pressure Equation
LIT Methods
Pressure-Squared Method
Pressure-Approximation Method
Pseudopressure Approach
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15. Future IPR: Back-Pressure Equation
The performance coefficient C is considered a pressuredependent parameter and adjusted with each change of
the reservoir pressure according to the following
expression:
The value of n is considered essentially constant.
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16. Future IPR: LIT Methods
The laminar flow coefficient a and the inertial-turbulent
flow coefficient b of any of the previous LIT methods, are
modified according to the following simple relationships:
Pressure-Squared Method
• The coefficients a and b of pressure-squared are modified to
account for the change of the reservoir pressure from p–r1 to p–
r2 by adjusting the coefficients as follows:
• (the subscripts 1 and 2 represent conditions at reservoir pressure
p–r1 to p–r2, respectively.)
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17. Future IPR: LIT Methods (Cont.)
Pressure-Approximation Method
Pseudopressure Approach
• The coefficients a and b of the pseudo-pressure approach are
essentially independent of the reservoir pressure and they can be
treated as constants.
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18. Current and Future IPR Comparison
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19.
20. Horizontal Gas Well
Many low permeability gas reservoirs are
historically considered to be noncommercial due to
low production rates.
Most vertical wells drilled in tight gas reservoirs are
stimulated using hydraulic fracturing and/or acidizing
treatments to attain economical flow rates.
In addition, to deplete a tight gas reservoir, vertical
wells must be drilled at close spacing to efficiently
drain the reservoir.
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21. Horizontal Gas Well (Cont.)
This would require a large number of vertical wells.
In such reservoirs, horizontal wells provide an attractive
alternative to effectively deplete tight gas reservoirs and
attain high flow rates.
Joshi (1991) points out those horizontal wells are
applicable in both low-permeability reservoirs as
well as in high-permeability reservoirs.
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22. Effective Wellbore Radius
in Horizontal Gas Well
In calculating the gas
flow rate from a
horizontal well, Joshi
introduced the concept
of the effective
wellbore radius r′w into
the gas flow equation.
The effective wellbore
radius is given by:
2013 H. AlamiNia
Where
L = length of the
horizontal well, ft
h = thickness, ft
rw = wellbore radius, ft
reh = horizontal well
drainage radius, ft
a = half the major axis of
drainage ellipse, ft
A = drainage area, acres
Reservoir Engineering 1 Course: Gas Well Performance / Driving Mechanisms
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23. Qg Calculation
from a Horizontal Gas Well
Methods of calculating the horizontal well drainage area A are
presented in previous lecture.
For a pseudosteady-state flow, Joshi expressed Darcy’s equation
of a laminar flow in the following two familiar forms:
Pressure-Squared Form
Where Qg = gas flow rate, Mscf/day
s = skin factor
k = permeability, md
T = temperature, °R
Pseudo-Pressure Form
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24. IPR Curve for Horizontal Gas Well
For turbulent flow, Darcy’s equation must be
modified to account for the additional pressure
caused by the non-Darcy flow by including the ratedependent skin factor DQg.
In practice, the back-pressure equation and the LIT
approach are used to calculate the flow rate and
construct the IPR curve for the horizontal well.
Multirate tests, i.e., deliverability tests, must be
performed on the horizontal well to determine the
coefficients of the selected flow equation.
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25.
26.
27. Reservoir Classification
Each reservoir is composed of a unique
combination of geometric form, geological rock
properties, fluid characteristics, and primary drive
mechanism.
Although no two reservoirs are identical in all
aspects, they can be grouped according to the
primary recovery mechanism by which they
produce.
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28. Driving Mechanisms Characteristics
It has been observed that each drive mechanism has
certain typical performance characteristics in terms of:
Ultimate recovery factor
Pressure decline rate
Gas-oil ratio
Water production
The recovery of oil by any of the natural drive
mechanisms is called primary recovery.
The term refers to the production of hydrocarbons from a
reservoir without the use of any process (such as fluid
injection) to supplement the natural energy of the reservoir.
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29. Primary Recovery Mechanisms
For a proper understanding of reservoir behavior
and predicting future performance, it is necessary
to have knowledge of the driving mechanisms that
control the behavior of fluids within reservoirs.
The overall performance of oil reservoirs is largely
determined by the nature of the energy, i.e., driving
mechanism, available for moving the oil to the
wellbore.
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30. Driving Mechanisms
There are basically six driving mechanisms that
provide the natural energy necessary for oil
recovery:
Rock and liquid expansion drive
Depletion drive
Gas cap drive
Water drive
Gravity drainage drive
Combination drive
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31.
32. Rock and Liquid Expansion
At pressures above the bubble-point pressure, crude oil
(in undersaturated reservoirs), connate water, and rock
are the only materials present. As the reservoir
pressure declines, the rock and fluids expand due to
their individual compressibilities.
As the expansion of the fluids and reduction in the pore
volume occur with decreasing reservoir pressure, the
crude oil and water will be forced out of the pore space
to the wellbore.
This driving mechanism is considered the least efficient
driving force and usually results in the recovery of only
a small percentage of the total oil in place.
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33. The Depletion Drive Mechanism
This driving form may also be referred to by the
following various terms:
Solution gas drive
Dissolved gas drive
Internal gas drive
In this type of reservoir, the principal source of
energy is a result of gas liberation from the crude
oil and the subsequent expansion of the solution
gas as the reservoir pressure is reduced.
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34. Production Data
of a Solution-Gas-Drive Reservoir
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35. Gas Cap Drive
Gas-cap-drive reservoirs can be identified by the
presence of a gas cap with little or no water drive.
Due to the ability of the gas cap to expand, these
reservoirs are characterized by a slow decline in the
reservoir pressure. The natural energy available to
produce the crude oil comes from the following two
sources:
Expansion of the gas-cap gas
Expansion of the solution gas as it is liberated
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36. Production Data for a Gas-Cap-Drive
Reservoir
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37. The Water-Drive Mechanism
Many reservoirs are bounded on a portion or all of
their peripheries by water bearing rocks called
aquifers.
The aquifers may be so large compared to the
reservoir they adjoin as to appear infinite for all
practical purposes, and they may range down to
those as small as to be negligible in their effects on
the reservoir performance.
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38. Types of Aquifers
The aquifer itself may be entirely bounded by
impermeable rock so that the reservoir and aquifer
together form a closed (volumetric) unit.
On the other hand, the reservoir may be
outcropped at one or more places where it may be
replenished by surface water.
Regardless of the source of water, the water drive is
the result of water moving into the pore spaces
originally occupied by oil, replacing the oil and
displacing it to the producing wells.
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39. Reservoir Having Artesian Water Drive
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40. Aquifer Geometries
It is common to speak
of edge water or
bottom water in
discussing water influx
into a reservoir.
Bottom water occurs
directly beneath the oil
and edge water occurs
off the flanks of the
structure at the edge of
the oil
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41. Production Data
for a Water-Drive Reservoir
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43. The Combination-Drive Mechanism
The driving mechanism most commonly
encountered is one in which both water and free
gas are available in some degree to displace the oil
toward the producing wells.
Two combinations of driving forces can be present
in combination drive reservoirs. These are
(1) Depletion drive and a weak water drive and;
(2) Depletion drive with a small gas cap and a weak
water drive.
Then, of course, gravity segregation can play an
important role in any of the aforementioned drives.
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44. Combination-Drive Reservoir
The most
common type
of drive
encountered,
therefore, is a
combinationdrive
mechanism as
illustrated in
Figure.
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45. 1. Ahmed, T. (2006). Reservoir engineering
handbook (Gulf Professional Publishing). Ch8
& 11