This document discusses gas lift, a method of artificial lift used in oil production. It describes how gas lift works by injecting gas into the wellbore to reduce fluid density and allow the well to flow. The key components of a gas lift system include the gasline, tubing, packer, and gas lift valves. Continuous and intermittent gas lift methods are examined. Advantages include flexibility and ability to handle high production rates, while disadvantages include needing a gas source and potential high installation costs. Troubleshooting techniques and factors that influence gas lift design are also overviewed.
This document was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
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.
Production tubing is installed in oil and gas wells to allow hydrocarbons to flow from the reservoir to the surface while protecting the casing from reservoir fluids. Tubing is specified based on its size, length, grade, and connection type. Common tubing sizes range from 2-3/8" to 4-1/2" in diameter. Tubing joints are typically 20-48 feet in length. Tubing grade depends on the application and is chosen based on strength, corrosion resistance, and availability. Connections can be either upset or non-upset threaded types.
This document provides information on gas lift valve mechanics, including the three basic types of gas lift valves, how they operate, and the forces involved in opening and closing them. It discusses unloading valves, orifice valves, and how gas lift valves close in sequence from the bottom of the well upward. Diagrams show the components of different gas lift valve designs and the formulas used to calculate valve opening and closing pressures.
The slide-pack covers a large variety of artificial lift methods. Explanations are supported by breakdown of pros and cons, calculations and questions. Questions will shed light of roughly how to decide which method(s) to use in a specific case.
introduction to ESP (electrical submersible pump), working principle of ESP (electrical submersible pump), Application of ESP (electrical submersible pump), Uses of ESP in Oil Well, Specification of ESP (electrical submersible pump), New varieties of ESP (electrical submersible pump).
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 was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
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.
Production tubing is installed in oil and gas wells to allow hydrocarbons to flow from the reservoir to the surface while protecting the casing from reservoir fluids. Tubing is specified based on its size, length, grade, and connection type. Common tubing sizes range from 2-3/8" to 4-1/2" in diameter. Tubing joints are typically 20-48 feet in length. Tubing grade depends on the application and is chosen based on strength, corrosion resistance, and availability. Connections can be either upset or non-upset threaded types.
This document provides information on gas lift valve mechanics, including the three basic types of gas lift valves, how they operate, and the forces involved in opening and closing them. It discusses unloading valves, orifice valves, and how gas lift valves close in sequence from the bottom of the well upward. Diagrams show the components of different gas lift valve designs and the formulas used to calculate valve opening and closing pressures.
The slide-pack covers a large variety of artificial lift methods. Explanations are supported by breakdown of pros and cons, calculations and questions. Questions will shed light of roughly how to decide which method(s) to use in a specific case.
introduction to ESP (electrical submersible pump), working principle of ESP (electrical submersible pump), Application of ESP (electrical submersible pump), Uses of ESP in Oil Well, Specification of ESP (electrical submersible pump), New varieties of ESP (electrical submersible pump).
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
WELL COMPLETION, WELL INTERVENTION/ STIMULATION, AND WORKOVERAndi Anriansyah
This document discusses various well completion, intervention, and workover topics including:
- Well completion involves preparing the well for production by installing equipment like casing and tubing.
- Open hole and cased hole completions are described, along with advantages and disadvantages of each.
- Well intervention operations like scale removal, acidizing, and sand cleaning are performed during production.
- Formation damage from fluids introduced into the well is also discussed.
- Stimulation techniques like acidizing and hydraulic fracturing aim to increase well productivity. The document outlines the processes, equipment, and evaluation of these operations.
- Other topics covered include intelligent well completions, perforating, sand control, squeeze cement
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
Sucker rod pumps are a type of artificial lift used in oil wells that involves components both above and below ground. The surface pumping unit is connected via sucker rods to the subsurface pump located downhole. The pumping cycle involves the plunger moving up and down inside the barrel, using the traveling or standing valves to draw fluid into the barrel on the upstroke and push it up on the downstroke. Sucker rod pumps are suitable for shallow wells producing 10-1000 bbl/day but become less effective at greater depths or in wells with high gas levels.
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
An electrical submersible pump (ESP) is used to increase the pressure of well fluid and push it to the surface from deeper wells. It consists of a subsurface electric motor, seal section to connect the motor to multiple centrifugal pump stages, and an electric cable. The motor turns at high rpm to power the pump stages, each with an impeller and diffuser, to boost the fluid pressure stage by stage until it reaches the surface. ESPs provide high production volumes but require high voltages and more maintenance due to wear from sand and fluids. They are advantageous for deep wells but can have issues with sand and require careful installation and operation.
This document summarizes a project on well control and blowout prevention. It discusses causes of kicks such as insufficient mud weight and lost circulation. It describes shut-in procedures for land and offshore rigs which involve closing blowout preventers. It covers obtaining and interpreting shut-in pressures to determine formation and trapped pressures. Kill methods like wait and weight, engineer's method, and concurrent method are outlined. Variables that affect kill procedures like influx type and volume are identified. The document provides an example case study of a well control complication and kill operation.
After drilling is completed, wells undergo completion procedures to prepare them for production. This involves setting production casing and cementing it through the target zone. Tubing is run inside the casing with a packer to isolate the production zone. A Christmas tree is installed to control flow. Completion types include open hole, liners, and perforated casing. Perforating creates holes through casing into the formation. Some formations require stimulation like acidizing to improve permeability or fracturing to create conductive fractures held open by proppant. This increases flow into the wellbore.
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
Gas Lift Design: Comparative Study of Continuous and Intermittent Gas Lift (C...Nicodeme Feuwo
This document was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
Petroleum Production Engineering - PerforationJames Craig
This document provides an overview of perforation for oil and gas wells. It discusses key objectives and components of perforation including shaped charges, explosives, perforating guns, and efficiency factors. It also covers well and reservoir characteristics relevant to perforation and provides equations for calculating perforation skin effects on well performance. The high-level goal of perforation is to establish communication between the wellbore and formation while maintaining reservoir inflow capacity.
This document provides procedures for well test operations. It describes various types of well tests including drawdown, build-up, and deliverability tests. It outlines responsibilities for company and contractor personnel involved in well testing. Safety barriers for well tests include well test fluid, mechanical barriers, casing overpressure valves, and more. Test string equipment, surface equipment, data acquisition methods, sampling procedures, and other well testing steps are also covered. The document aims to provide uniform guidelines for Agip's well testing operations worldwide.
The document discusses various artificial lift technologies used in oil production, including reciprocating rod lift systems, progressing cavity pumps, gas lift systems, plunger lift systems, hydraulic lift systems, and electric submersible pumps. It provides details on the advantages and limitations of each system, as well as parameters for determining appropriate applications, such as operating depth, volume, temperature, and wellbore characteristics. Selection of the optimal artificial lift method involves a systematic evaluation process to maximize return on investment.
The document discusses well control systems used in drilling engineering. It describes the components of the well control system including sensors to detect fluid influx, the blowout preventer (BOP) stack, choke manifold, and associated equipment. The BOP stack is made up of different sealing devices like annular and ram BOPs that can shut off the well in an emergency. Sensors and monitoring systems are used to detect kicks and monitor drilling parameters important for well control. The overall system aims to safely detect, control, and remove any unexpected influx of formation fluids into the wellbore.
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.
Production optimization using gas lift techniqueJarjis Mohammed
After completed the drilling, set the tubing and completed the well successfully, Petroleum engineers realize that the hydrocarbon fluid won't lift up from bottom hole to the surface by its reservoir drives which are mainly gas cap or water drive. Simply the gas lift technique is to reduce the density of hydrocarbon fluid inside the well to lift it to the surface by injecting compressed gas.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
Casing Seat depth and Basic casing design lecture 4.pdfssuserfec9d8
1. The maximum gas kick pressure from the total depth as the internal pressure.
2. Formation pore pressure at the casing shoe as the external pressure.
3. The casing must be designed to withstand the difference between the maximum internal gas kick pressure and external pore pressure, known as the resultant pressure.
The document discusses enhanced oil recovery (EOR) methods, focusing on steam injection. It defines EOR as techniques for extracting more crude oil from reservoirs beyond primary and secondary recovery methods. Steam injection is a thermal EOR method that involves injecting steam into reservoirs to lower oil viscosity and produce more oil. There are two main steam injection techniques - cyclic steam stimulation (also called huff-and-puff) which alternates between steam injection and production from single or multiple wells, and steam flooding which continuously injects steam into reservoirs to displace oil towards production wells. The document outlines some advantages and disadvantages of steam injection and economic considerations.
The document discusses various artificial lift methods used in oil and gas production. It provides diagrams and explanations of gas lift systems, beam pumping systems, and rod pumping systems. The key points covered include:
- Gas lift uses high pressure gas injected into the wellbore to reduce bottomhole pressure and increase production. Continuous and intermittent gas lift systems are described.
- Beam pumping units use sucker rods and a reciprocating downhole pump to lift fluids. Components of rod pumping systems like the plunger and valves are detailed.
- Factors affecting selection and performance of artificial lift methods are addressed, including production rates, reservoir properties, well depth, and economics.
Artificial lift systems are used to increase production from oil wells that can no longer produce on their own. The main types discussed are rod pumping, progressing cavity pumping, electric submersible pumping, gas lifting, and plunger lift. Key factors in selecting a system include the well's production rate, depth, fluid properties, and economic considerations such as capital and operating costs. Performance is evaluated using productivity index curves, decline curves, and analyzing the impact of gas injection on flowing bottomhole pressure.
WELL COMPLETION, WELL INTERVENTION/ STIMULATION, AND WORKOVERAndi Anriansyah
This document discusses various well completion, intervention, and workover topics including:
- Well completion involves preparing the well for production by installing equipment like casing and tubing.
- Open hole and cased hole completions are described, along with advantages and disadvantages of each.
- Well intervention operations like scale removal, acidizing, and sand cleaning are performed during production.
- Formation damage from fluids introduced into the well is also discussed.
- Stimulation techniques like acidizing and hydraulic fracturing aim to increase well productivity. The document outlines the processes, equipment, and evaluation of these operations.
- Other topics covered include intelligent well completions, perforating, sand control, squeeze cement
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
Sucker rod pumps are a type of artificial lift used in oil wells that involves components both above and below ground. The surface pumping unit is connected via sucker rods to the subsurface pump located downhole. The pumping cycle involves the plunger moving up and down inside the barrel, using the traveling or standing valves to draw fluid into the barrel on the upstroke and push it up on the downstroke. Sucker rod pumps are suitable for shallow wells producing 10-1000 bbl/day but become less effective at greater depths or in wells with high gas levels.
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
An electrical submersible pump (ESP) is used to increase the pressure of well fluid and push it to the surface from deeper wells. It consists of a subsurface electric motor, seal section to connect the motor to multiple centrifugal pump stages, and an electric cable. The motor turns at high rpm to power the pump stages, each with an impeller and diffuser, to boost the fluid pressure stage by stage until it reaches the surface. ESPs provide high production volumes but require high voltages and more maintenance due to wear from sand and fluids. They are advantageous for deep wells but can have issues with sand and require careful installation and operation.
This document summarizes a project on well control and blowout prevention. It discusses causes of kicks such as insufficient mud weight and lost circulation. It describes shut-in procedures for land and offshore rigs which involve closing blowout preventers. It covers obtaining and interpreting shut-in pressures to determine formation and trapped pressures. Kill methods like wait and weight, engineer's method, and concurrent method are outlined. Variables that affect kill procedures like influx type and volume are identified. The document provides an example case study of a well control complication and kill operation.
After drilling is completed, wells undergo completion procedures to prepare them for production. This involves setting production casing and cementing it through the target zone. Tubing is run inside the casing with a packer to isolate the production zone. A Christmas tree is installed to control flow. Completion types include open hole, liners, and perforated casing. Perforating creates holes through casing into the formation. Some formations require stimulation like acidizing to improve permeability or fracturing to create conductive fractures held open by proppant. This increases flow into the wellbore.
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
Gas Lift Design: Comparative Study of Continuous and Intermittent Gas Lift (C...Nicodeme Feuwo
This document was produced as part of my final year project of training to obtain a petroleum engineering diploma.
The aim of this project is to make a comparative study between continuous and intermittent gas lift systems based on real data from an oil well in Algeria, and to choose the system best suited to increase the production of the well.
This study was carried out by a manual design using the method of “fixed pressure drop” for the continuous gas lift system and “fallback gradient” method for intermittent gas lift system.
We were able to determine at the end of this study that the system best suited to the current conditions of our well would be the intermittent gas lift system and we also proposed that it should be combine with the "plunger lift " system in order to increase the efficiency of the intermittent gas lift system by eliminating problems linked to the phenomenon of" fallback " thus increase the production of our wells.
Petroleum Production Engineering - PerforationJames Craig
This document provides an overview of perforation for oil and gas wells. It discusses key objectives and components of perforation including shaped charges, explosives, perforating guns, and efficiency factors. It also covers well and reservoir characteristics relevant to perforation and provides equations for calculating perforation skin effects on well performance. The high-level goal of perforation is to establish communication between the wellbore and formation while maintaining reservoir inflow capacity.
This document provides procedures for well test operations. It describes various types of well tests including drawdown, build-up, and deliverability tests. It outlines responsibilities for company and contractor personnel involved in well testing. Safety barriers for well tests include well test fluid, mechanical barriers, casing overpressure valves, and more. Test string equipment, surface equipment, data acquisition methods, sampling procedures, and other well testing steps are also covered. The document aims to provide uniform guidelines for Agip's well testing operations worldwide.
The document discusses various artificial lift technologies used in oil production, including reciprocating rod lift systems, progressing cavity pumps, gas lift systems, plunger lift systems, hydraulic lift systems, and electric submersible pumps. It provides details on the advantages and limitations of each system, as well as parameters for determining appropriate applications, such as operating depth, volume, temperature, and wellbore characteristics. Selection of the optimal artificial lift method involves a systematic evaluation process to maximize return on investment.
The document discusses well control systems used in drilling engineering. It describes the components of the well control system including sensors to detect fluid influx, the blowout preventer (BOP) stack, choke manifold, and associated equipment. The BOP stack is made up of different sealing devices like annular and ram BOPs that can shut off the well in an emergency. Sensors and monitoring systems are used to detect kicks and monitor drilling parameters important for well control. The overall system aims to safely detect, control, and remove any unexpected influx of formation fluids into the wellbore.
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.
Production optimization using gas lift techniqueJarjis Mohammed
After completed the drilling, set the tubing and completed the well successfully, Petroleum engineers realize that the hydrocarbon fluid won't lift up from bottom hole to the surface by its reservoir drives which are mainly gas cap or water drive. Simply the gas lift technique is to reduce the density of hydrocarbon fluid inside the well to lift it to the surface by injecting compressed gas.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
Casing Seat depth and Basic casing design lecture 4.pdfssuserfec9d8
1. The maximum gas kick pressure from the total depth as the internal pressure.
2. Formation pore pressure at the casing shoe as the external pressure.
3. The casing must be designed to withstand the difference between the maximum internal gas kick pressure and external pore pressure, known as the resultant pressure.
The document discusses enhanced oil recovery (EOR) methods, focusing on steam injection. It defines EOR as techniques for extracting more crude oil from reservoirs beyond primary and secondary recovery methods. Steam injection is a thermal EOR method that involves injecting steam into reservoirs to lower oil viscosity and produce more oil. There are two main steam injection techniques - cyclic steam stimulation (also called huff-and-puff) which alternates between steam injection and production from single or multiple wells, and steam flooding which continuously injects steam into reservoirs to displace oil towards production wells. The document outlines some advantages and disadvantages of steam injection and economic considerations.
The document discusses various artificial lift methods used in oil and gas production. It provides diagrams and explanations of gas lift systems, beam pumping systems, and rod pumping systems. The key points covered include:
- Gas lift uses high pressure gas injected into the wellbore to reduce bottomhole pressure and increase production. Continuous and intermittent gas lift systems are described.
- Beam pumping units use sucker rods and a reciprocating downhole pump to lift fluids. Components of rod pumping systems like the plunger and valves are detailed.
- Factors affecting selection and performance of artificial lift methods are addressed, including production rates, reservoir properties, well depth, and economics.
Artificial lift systems are used to increase production from oil wells that can no longer produce on their own. The main types discussed are rod pumping, progressing cavity pumping, electric submersible pumping, gas lifting, and plunger lift. Key factors in selecting a system include the well's production rate, depth, fluid properties, and economic considerations such as capital and operating costs. Performance is evaluated using productivity index curves, decline curves, and analyzing the impact of gas injection on flowing bottomhole pressure.
Gas Turbine Training Power Point -SampleAli Rafiei
The document provides an overview of gas turbine evolution and components. It discusses the development of axial compressors and turbines from the 18th century ideas of John Barber and John Dumball. It then summarizes the key components of modern gas turbines, including compressors, combustion chambers, turbines, lubrication systems, and controls. Examples are given for Siemens SGT600 components like the compressor, combustion chamber, and control modes.
The document discusses gas lift, including the concepts, advantages, limitations, types, and design methods. Some key points:
- Gas lift reduces flowing bottom hole pressure and liquid holdup to improve production. Continuous and intermittent flow are the main types.
- Advantages include low cost, adjustable rates, surface control, and independence from downhole conditions. Limitations include needing a gas source and dealing with heavy oils.
- Design methods covered include graphical, unloading line, percent load, and fallback for intermittent lift. Continuous flow uses outflow curves and considers temperature.
- Factors like fluid properties, well configuration, pressure, and correlations affect outflow performance. Gas gradients are calculated based on properties
Multiphase Advanced Pumping System for Artificial Lift MAPS-ALYuriFairuzov
Conventional artificial lift devices, such as a downhole pump or a plunger, are designed to be placed in a vertical oil or gas well. Placing the downhole pump in a deviated section of a horizontal well to reduce the back pressure on the reservoir or the amount of free gas that enters the pump results in high operating costs due to pump failures. In wells with plunger lift systems, the deviation can affect adversely plunger performance and c│reate problems with plunger recovery. Increase estimated ultimate recovery (EUR) and reduce the operating costs using the MAPS-AL multiphase advanced pumping system for artificial lift, a unique technology solution for horizontal wells.
The document discusses compressor working principles and types. It provides the following key points:
1) There are two basic principles of air or gas compression: positive displacement and dynamic compression. Positive displacement compressors reduce volume to increase pressure while dynamic compressors convert velocity to pressure.
2) Compressor types include centrifugal and reciprocating compressors. Centrifugal compressors use radial diffusers to increase pressure via Bernoulli's principle while reciprocating compressors use pistons in cylinders.
3) Capacity control methods for compressors include inlet guide vanes, blow-off valves, and modulating control to vary output between 100% to 10%. Operating parameters like inlet pressure and temperature influence compressor flow and power requirements
Roth regenerative turbine chemical duty pumps provide continuous, high pressure pumping of non-lubricating and corrosive liquids. These regenerative turbine pumps are provided with one piece, machined self-centering impellers for operation with a wide variety of chemicals .
This document provides an overview of sucker rod pumps (SRP), which are the oldest and most widely used type of artificial lift for oil wells. It describes the main components of an SRP system, including the surface pumping unit and sub-surface pumping unit. The pumping cycle and ideal pumping speed are explained. The document also discusses pump operations in gaseous fluids and lists the advantages and disadvantages of SRP systems. It provides illustrations of the API designation systems for subsurface and surface pumps.
This document provides an introduction to artificial lift methods used in oil production. It discusses the basic principles of how reservoir pressure drives oil to the surface. When reservoir pressure declines over time, artificial lift is needed to supplement the natural reservoir forces and maintain production rates. The two primary categories of artificial lift discussed are compressed gas lift and mechanical lift. Specific methods covered include continuous and intermittent gas lift, sucker rod pumps, electrical submersible pumps, progressive cavity pumps, and jet pumps. Key factors for selecting a lift method include well characteristics, production rates, well depth, and economic considerations. The advantages and disadvantages of gas lift and sucker rod pumping are also summarized.
Artificial lift overview with full description for the used methods. The function and the objective of each component for each artificial lift mean is described.
1) Progressive cavity pumps (PCPs) are increasingly being used as an artificial lift solution for producing low API crude from oil fields, as they can effectively lift heavy crudes along with sand.
2) PCPs have an advantage over other artificial lift methods for conditions involving heavy crude production and high sand content. They use a rotor-stator design that creates a sealed, progressing cavity to lift fluids in a continuous, non-pulsating flow.
3) Carefully selecting the appropriate artificial lift technology for each well based on reservoir and production parameters is important. Matrix classification and analytical comparison tables can aid in this selection process, indicating that PCPs are well-suited for fields producing low API
The Piston Less Pump Working Explained in PPTlingarajrsat
This document summarizes a pistonless pump designed for rocket fuel. It introduces the pistonless pump as an alternative to turbo pumps that is simpler, cheaper, and lighter. The summary describes how the pistonless pump works using pressurized gas to cycle fuel through two chambers alternately without any moving pistons. Advantages are listed as low cost, weight, and few moving parts compared to turbo pumps. Applications mentioned include use in deep space exploration missions.
This document provides information on pilot operated pressure relief valves (POPRVs), including:
- Definitions and basic operation where the pilot controls the main valve opening and closing pressures.
- Types of pilots such as pop action pilots for gas/mixed phase service and modulating pilots.
- Manufacturers, applications, features/benefits, and options like remote sensing and backflow prevention.
- Code status where POPRVs are ASME certified and testing procedures.
- Examples of Anderson Greenwood POPRV models like the Series 200 pop pilot and Series 400 modulating pilot.
The document discusses the major components of steam turbines, including the casing, nozzles, blades, rotor, bearings, governors, and safety devices. It describes the functions of key parts like the nozzle, blades, governors, and oil pumps. It also classifies steam turbines based on the method of steam expansion, flow direction, final pressure, number of stages, and pressure. The document provides information on standards, parameter ranges, troubleshooting, and starting procedures for steam turbines.
Pumster Company introduction 2018
We are a leading company in high pressure equipment.
Pumster creats the best profit with transparent management and innovative technology.
http://www.pumster.com/en/
The leading manufacturer in High pressure pump
- The specialized company in Air Gas Booster, Air Liquid pump, metering pump, the pressure testing machine, etc.
The document provides a list of parts for a radiator and its attaching parts for a 1666 Case IH Axial-Flow Combine from 1993 to 1994. It includes the radiator, radiator cap, shroud ring and bolts, seals for the radiator to shroud and radiator to air chute, a drain valve, radiator mounting shock absorbers, bolts and nuts for attaching the radiator supports, and self-tapping screws. Part numbers and quantities are provided for each part.
TangentFlow Technical Paper FINAL 221015 OCT 22 2015Corbin Coyes
The document discusses the design and testing of a new ball valve insert called the vortex insert. The goal was to improve the efficiency and reliability of sucker rod pumps. Laboratory testing found that a prototype insert with a 10mm clockwise helical twist reduced pressure drop by an average of 40% compared to conventional bar-bottom inserts, resulting in 58% more flow. Field data also showed increased production and a 25% reduction in operating costs after installing the new inserts. The vortex insert design aims to minimize issues like pressure drop, gas breakout, and solids buildup that reduce pump efficiency by forcing fluid into a stabilizing vortex motion through the ball valve.
TangentFlow Technical Paper FINAL 221015 OCT 22 2015
13 artificial-lift
1. Copyright 2007, , All rights reserved
Artificial Lift
Overview of Methods, Equipment and Operation
2. Copyright 2007, , All rights reserved
.
Pe initial
PRESSUREPwh
DEPTH
Well pressure gradient
Inflow Performance
Pwf initial
Pe actual
Pwf actual
3. Copyright 2007, , All rights reserved
Gas Lift
Principle
Equipment
Types
Operation
Troubleshooting & Control
Advantages & disadvantages
4. Copyright 2007, , All rights reserved 4
GAS INJECTION
PRODUCED FLUIDSURFACE PRESSURE
SANDFACE
PRESSURE
BHFP
RESERVOIR
PRESSURE
Gas Lift
Injection of gas in the annulus
to decrease the hydrostatic
head below bottom hole
flowing pressure and allow
the well to flow.
5. Copyright 2007, , All rights reserved
Gaslift Equipment
Gasline
Surface casing
Production casing
Tubing
Packer
Flowline
Side pocket mandrel
Bellows
Section
Pilot
Section
Gaslift valve
Gaslift completion
7. Copyright 2007, , All rights reserved 7
Types of Gas Lift
CONTINUOUS FLOW GAS LIFT Steady State Flow;
mechanisms are lowering density, expanding gas and
pushing to surface. P & T remain constant at process plant.
INTERMITTENT GAS LIFT Batch Production; for low
productivity wells; process problems.
8. Copyright 2007, , All rights reserved
Continuous Gaslift
Gasline
Flowline
Unloading valve
Operating valve
Tubing
Packer
9. Copyright 2007, , All rights reserved
Pr
OPENING PRESSURE
.
Val. 1
Val. 2
Val. 3
A
B
C
Pwh
DEPTH
Gaslift Valve Operation
VIDEO
10. Copyright 2007, , All rights reserved 10
Unloading Gas Lift Valve
Normally required during unloading phase only
Open only when annulus and tubing pressures are high
enough to overcome valve set pressure
Valve closes after transfer to next station
May be spring or nitrogen charged
11. Copyright 2007, , All rights reserved 11
Operating Gas Lift Valve
Typically an ‘orifice’ type Gas lift valve
always open - allows gas across Passage whenever correct
differential exists
Gas injection controlled by size and differential across
replaceable choke
Back-check prevents reverse flow of well fluids from the
production conduit
12. Copyright 2007, , All rights reserved 12
Gas Injection Rate
DOWNSTREAM PRESSURE (PSI)
SUB-CRITICAL
FLOW
PCASING
PTUBING = 55%
ORIFICE FLOW
GASINJECTIONRATE(MMSCF/D)
Gas passage through the orifice valve
13. Copyright 2007, , All rights reserved
LIQUID PRODUCTION RATE (QL)
WELLFLOWINGPRESSURE(Pwf)
Well inflow
Pr
TASADEPRODUCCION(QL)
GAS INJECTION RATE(Qgi)
Optimum Economical
Maximum Production
Gaslift injection
14. Copyright 2007, , All rights reserved
Intermittent Gaslift
Gasline
Flowline
Unloading valve
Operating valve
Tubing
Packer
15. Copyright 2007, , All rights reserved
Gasline
Flowline
Unloading valve
Operating valve
Tubing
Packer
Plungerlift
16. Copyright 2007, , All rights reserved
Typical Range Maximum
• Depth (feet) 2.000 – 10.000 15.000
• Production (BPD) 100 – 10.000 20.000
• Temperature (°F) 100 – 250 N/D
Typical Operating Conditions
17. Copyright 2007, , All rights reserved 17
Gaslift Well
3-PHASE FLOWS
RICH GAS
DRY GAS
CRUDE OIL
DRY GAS
LNG
GAS
MANIFOLD
GAS PLANT
FLOW
STATION
WATER
GASLIFT
MANIFOLD
Surface Gaslift Control
18. Copyright 2007, , All rights reserved 18
Surface Gaslift Control
GASLIFT MANIFOLD
Manual Flow Control Valve
Actuated Flow Control Valve
19. Copyright 2007, , All rights reserved
Surface Gaslift Control
INDIRECT METERING OF GAS FLOW TO THE WELL
20. Copyright 2007, , All rights reserved
Connected to the
production casing valve
to record casing-tubing
annulus pressure.
Connected between the left
wing valve and the choke
box, to record WHP
Surface Gaslift Control
21. Copyright 2007, , All rights reserved
Surface Gaslift Control
CONTINUOUS FLOW
INTERMITTENT FLOW
CASING PRESSURE
WELLHEAD PRESSURE
22. Copyright 2007, , All rights reserved 22
Advantages of Gas Lift
Low initial downhole equipment costs
Low operational and maintenance cost
Simplified well completions
Flexibility - can handle rates from 10 to 50,000 bpd
Can best handle sand / gas / well deviation
Intervention relatively less expensive
23. Copyright 2007, , All rights reserved 23
Disadvantages of Gas Lift
Must have a source of gas
– Imported from other fields
– Produced gas - may result in start up problems
Possible high installation cost
– Top sides modifications to existing platforms
– Compressor installation
Limited by available reservoir pressure and bottom hole
flowing pressure
Efficiency decreases while BW&S increases
24. Copyright 2007, , All rights reserved 24
Summary of Gaslift Requirements
Maximize oil production
Minimize well intervention (especially in subsea wells)
Maximize design flexibility without compromising production
Maximize depth of injection
Well stability
Uncertainties in reservoir performance
Range of reservoir pressures over well life
Range of watercuts over well life
Range of gas injection rates
Valve port sizing and gas passage pressure drops in system
Valve performance
25. Copyright 2007, , All rights reserved 25
Types of Artificial Lift Pumping Methods
RP HP PCP ESP
26. Copyright 2007, , All rights reserved
Principle
Equipment
Operation
Troubleshooting & Control
Advantages and disadvantages
Mechanical Pumping (Sucker Rod Pumps)
27. Copyright 2007, , All rights reserved
Mechanical Pumping (Sucker Rod Pumps)
28. Copyright 2007, , All rights reserved 28
Mechanical Pumps
The first Artificial Lift method to be used and still very popular
Simple combination of a cylinder, a piston, intake valve and discharge
valve
Strokes from a few inches to less than 3,000 bopd
Suitable for viscous oils (+400 cp)
Main problems:
– low intake pressure
– high discharge pressure
– sand
– corrosion
– scales and deposits
– handling of gases and condensed vapors
29. Copyright 2007, , All rights reserved 29
Standing valve
Riding valve
Piston
Casing
Tubing
Rod string
Carrier Bar
Counter weight
Crank arm
Gearbox
Head
Elevator
Polished rod
Stuffing Box
Flow line
Gsa line
Sucker Rod Pumping
30. Copyright 2007, , All rights reserved 30
BARREL
RODS
PISTON
SETTING
BALLS
RIDING
VALVE
FLUID
Sucker Rod Pumping Equipment
31. Copyright 2007, , All rights reserved
Rod Pumping Troubleshooting and Control
31
32. Copyright 2007, , All rights reserved 32
DISPLACEMENT
LOAD
UPWARDS STROKE
DOWNWARDS
STROKE
NORMAL FUNCTIONING
ROD
PISTON
STANDIN
G VALVE
FLUID
DOWNWARD MOVEMENT UPWARD MOVEMENT
RIDING
VALVE
FLUID BARREL
Rod Pumping Troubleshooting and Control
33. Copyright 2007, , All rights reserved 33
Rod Pumping Troubleshooting and Control
34. Copyright 2007, , All rights reserved
Rod Pumping Typical Problems
34
Displacement
Load
Excessive Pumping Speed Restriction in the Well
Load
When a well is pumped at an
inadequate high speed in the beam’s
motor, it is observed in the chart that
the load decreases when beginning
the upwards piston stroke and
happens a closing in form of circle at
the end of this piston stroke.
Restrictions most of the cases reduce
the volume of fluid entering to the well
and causes in the chart an increasing
upwards load during the piston
stroke, but with excessive
displacement, which indicates little
work of the pump.
Displacement
35. Copyright 2007, , All rights reserved 35
Rod Pumping Typical Problems
Displacement
Load
Load
Displacement
The fluid blow happens when the
barrel of the pump does not fill
completely during the piston stroke
upwards and it is characterized by
a fast unloading at the end of the
downwards piston stroke.
The gas blow happens when the
pump fills partially with gas,
showing a chart’s shape very
similar to the one of the liquid lock,
but the unloading at the end of the
downwards piston stroke is less
pronounced.
Liquid Blow on the Pump Gas Blow on the Pump
36. Copyright 2007, , All rights reserved 36
Rod Pumping Typical Problems
Displacement
Load
Load
Displacement
Gas Blockade Full Drained
When the pump fills almost totally
with gas it is called gas blockade
and the chart is recognized
because the load decreases during
the upwards piston stroke and
shows very little work of the pump.
If there is no entrance of fluid to
the pump it generates a chart that
shows very few loads with normal
displacement, but without work of
the pump.
37. Copyright 2007, , All rights reserved
Electric Submersible Pumps (ESP)
38. Copyright 2007, , All rights reserved 38
Historical Perspective
1927 - El Dorado Kansas First
ESP Installation
Early 1930s - First Horizontal
Pumping Unit
1960s - First Variable Speed
Applications
1980s - First ESP Performance
Models
1990s First Subsea Completed
Applications
39. Copyright 2007, , All rights reserved
Pwh
PUMP
Pwh
Pwf Pr
Pdn
Pup
ΔP
gas
Pwf
PdnPup
Pressure
Depth
Pup = Suction pressure of pump
Pdn = Unloading pressure of pump
ESP System Functioning
Pr
40. Copyright 2007, , All rights reserved
LIQUID PRODUCTION RATE, QL
WELLFLOWINGPRESSURE(Pwf)
0
0
ΔP ΔP
Unloading pressure, Pdn
Suction Pressure, Pup
ESP System Functioning
41. Copyright 2007, , All rights reserved
ESP System Components
Electrical transformer
Well
head
Flare
box
Switch board
Tubing
Drainage valve
Retention valve
Unloading head
Pump
Intake
Protector
Power cable
Motor
Motor base
Casing
42. Copyright 2007, , All rights reserved 42
ESP Downhole System Components
In wells of high GOR a rotary gas
separator removes the free gas from
the produced fluid through the
casing-tubing annulus, the separator
prevents problems with gas blow and
cavitations, increasing the life of the
equipment.
The motors are bipolar, three-phase
and come full with a very refined
mineral oil to provide dielectric
resistance, lubrication for seals and
thermal conductivity.
The pumps are centrifugal of
several stages. Each stage consists
of a revolving impeller and a fixed
diffuser. The used materials are of
special metallurgy for optimal
operation in corrosive and/or
abrasive environments.
43. Copyright 2007, , All rights reserved 43
ESP Downhole System Components
Each "stage" consists of an
impeller and a diffuser. The
impeller takes the fluid and
imparts kinetic energy to it. The
diffuser converts this kinetic
energy into potential energy
(head).
44. Copyright 2007, , All rights reserved 44
Compliant Mounted Zirconia Radial Bearings
Head and Base Bearing
Stage Bearing
ESP Downhole System Components
45. Copyright 2007, , All rights reserved 45
ESP Downhole System Components
Typical fluid flow path in a
"mixed flow" stage.
46. Copyright 2007, , All rights reserved 46
ESP Downhole System Components
The next part of the system is the submergible motor. The motor
is a three phase, squirrel cage, two pole induction design.
PHASE 2
PHASE 3
PHASE 1
The three power phases are "Wye" connected within the motor
itself to establish a "neutral" point.
47. Copyright 2007, , All rights reserved 47
ESP Downhole System Components
Because of the way the stator is
wound, the three phase power
establishes a two pole magnetic
field within the stator.
The motor is called a squirrel
cage because this is what the
rotor looks like:
48. Copyright 2007, , All rights reserved 48
ESP Downhole System Components
The next major component of the ESP system is
the "Protector". The Protector is placed between
the pump and connects the motor shaft to the
pump shaft.
The Protector also houses the pump's upthrust
and downthrust bearings and provides for
pressure equalization between the outside of the
motor and the inside.
Unloading head
Pump
Intake w/ or wo/
Gas Separator
Protector
Motor
Motor base
49. Copyright 2007, , All rights reserved 49
ESP Downhole System Components
Prevents Wellbore Fluids Entering
Motor
Balances Pressure Between Motor &
Annulus
Carries Thrust Load of Pump
Shaft bushing
Labyrinth Chamber
Shaft Seals
Thrust Bearing
Filter Screen
Shedder
Elastomer Bag
Protector
50. Copyright 2007, , All rights reserved 50
ESP Downhole System Components
Between the Protector and the pump is the
pump intake section. This can be either a
standard ported intake or, as shown here,
a centrifugal gas separator to eliminate
free gas from the pumped fluid allowing it
to be produced up the annulus.
51. Copyright 2007, , All rights reserved 51
ESP Downhole System Components
Another component of the ESP system is the power cable.
This particular cable shows an optional chemical injection line
which can be incorporated within the cable itself.
52. Copyright 2007, , All rights reserved
OPERATING CONDITIONS:
Typical Range Maximum
• Depth (feet) 1,000 – 10,000 15,000
• Production (BPD) 100 – 20,000 90,000
• Temperature (°F) 100 – 275 400
ADVANTAGES:
• High temperature resistant
• Highly efficient
• Positive displacement
• High liquid rates
DISADVANTAGES:
• High efficiency
• Affected by high GOR
• Little resistant to solids and sand
ESP Operation
53. Copyright 2007, , All rights reserved 53
The Basic ESP System
Equipment diameters from 3.38” -
(A) series to 11.25” - (P) series
Casing Sizes - 4 1/2” to 13 5/8”
Variable Speed Available
Metallurgies to Suit Applications.
54. Copyright 2007, , All rights reserved 54
ESP Downhole System Operation
A centrifugal pump produces "constant head". This means that,
regardless of the fluid being pumped, it will be lifted to the same height as
any other fluid for the same flow rate.
Propane Water Oil
Head: The height
to which the pump
will "lift" the fluid
Curves for centrifugal pumps
are normally shown as flow
versus head in feet, meters,
or some other consistent
unit.
55. Copyright 2007, , All rights reserved 55
ESP Downhole System Operation
From this curves we can determine the head produced, brake
horsepower required and hydraulic efficiency at any flow rate.
R E D
R e v . B
S N 2 6 0 0 6P u m p P- S p . G r . 1 . 0 0
O p t i m u m O p
N o m i n a l H o u
S h a f t D i a m e
S h a f t C r o s s
M i n i m u m C a
6 0 0 - 3 2 0 0
5 . 3 8
0 . 8 7 5
0 . 6 0 1
7 . 0 0 0
b p d
i n c h e s
i n c h e s
i n 2
i n c h e s
S h a f t B r
H o u s i n g
S t a n d
H i g h S
S t a n d
B u t t r e
W e l d e
2 5 6
4 1 0
N / A
6 0 0 0
6 0 0 0
H p
H p
p s i
p s i
p s i
05 0 01 , 0 0 01 , 5 0 02 , 0 0 02 , 5 0 03 , 0 0 03 , 5 0 04 , 0 0 0
R E D
R e v . B
S N 2 6 0 0 6P u m p P- S p . G r . 1 . 0 0
O p t i m u m O p
N o m i n a l H o u
S h a f t D i a m e
S h a f t C r o s s
M i n i m u m C a
6 0 0 - 3 2 0 0
5 . 3 8
0 . 8 7 5
0 . 6 0 1
7 . 0 0 0
b p d
i n c h e s
i n c h e s
i n 2
i n c h e s
S h a f t B r
H o u s i n g
S t a n d
H i g h S
S t a n d
B u t t r e
W e l d e
2 5 6
4 1 0
N / A
6 0 0 0
6 0 0 0
H p
H p
p s i
p s i
p s i
EffHpFeet
ty - Barrels p
1 0 %
2 0 %
3 0 %
4 0 %
5 0 %
6 0 %
B
Q= 2 5
H= 4 6
P= 1 .
E= 6 8
1 0
2 0
3 0
4 0
5 0
6 0
0 . 5 0
1 . 0 0
1 . 5 0
2 . 0 0
2 . 5 0
3 . 0 0
56. Copyright 2007, , All rights reserved
OPERATION CONDITIONS:
Typical Range Máximum
• Depth (feet) 2.000 – 4.500 6.000
• Volume (BPD) 5 – 2.200 4.500
• Temperature (°F) 75 – 150 225
ADVANTAGES:
• Low investment, operating and maintenence
costs
• High efficiency
• Positive displacement
• Small size surface equipment
DISADVANTAGES:
• Medium to low resistance to high temperatures
• Low resistance to solids
• Incompatibility elastomers - fluid
Progressive Cavity Pumps (PCP)
57. Copyright 2007, , All rights reserved 57
Positive displacement pump without
valves
Delivers a consistent flow
Stator being stationary attached to
the tubing string
Rotor rotates driven from the surface
through the rod string and the stator
is attached to the tubing string
The rotor is a single threaded helix
and the stator is an elastomer lined
double threaded helical cavity.
The Progressive Cavity Pump
58. Copyright 2007, , All rights reserved
Opportunity of application:
• Deep wells that requires high
torque
• Horizontal and highly deviated
wells
• Rotating gas separator
Downhole Motor PCP