Distillation is a key separation process used in petroleum refining to separate crude oil into its various components like gasoline, kerosene, and diesel. Crude oil is first desalted and dewatered before being fed to a distillation unit where it is heated and separated based on differences in boiling points into various hydrocarbon fractions. Further refining processes like reforming, cracking, and hydrotreating are used to convert heavier fractions into lighter, more valuable products like gasoline.
Natural gas contains water that must be removed through dehydration. There are three main dehydration methods: direct cooling, adsorption, and absorption. Glycol absorption is most common, using triethylene glycol to continuously remove water down to 0.5 lb of H2O/MMSCF. Glycol dehydration has lower costs than alternatives due to easier regeneration and makeup of glycol, as well as less heat required per pound of water removed. Removing water prevents issues like reduced heating value, gas hydrate formation, and corrosion in downstream pipelines and equipment.
This document describes the process of solid bed gas dehydration. It begins with an introduction to gas dehydration and why it is needed to meet contractual water content specifications. It then covers determining the water content in a gas stream and corrections that must be made. The main part of the document discusses how solid bed dehydration systems work using adsorption onto a desiccant and provides details on the process, design considerations, example calculations, and heat requirements for regeneration. It concludes with a solved example to design a solid bed dehydration unit to treat a specific gas feed.
Crude oil production systems involve exploration, drilling, and surface production operations to extract crude oil and separate it from other fluids and gases. Surface production operations include separating the well effluent into gas, oil, and water streams using separators. The separated streams undergo further treatment, which may include dehydration to remove water, emulsion breaking, stabilization to control vapor pressure, and removal of impurities. Produced water is typically reinjected, while associated gas may be reinjected, used for power generation, or flared if not needed onsite. Wastes are also handled through treatment and disposal or reuse to protect the environment.
This document outlines the key steps in the liquefied natural gas (LNG) production process. It begins with extracting natural gas from the ground, then treating the gas to remove impurities. The treated gas is then condensed into a liquid by cooling it to -260°F through a multi-stage liquefaction process. The LNG is stored and transported in specialized cryogenic tanks on ships or trucks, then regasified back into gas form before being distributed through pipelines. The document provides details on each stage of the LNG value chain from production to regasification and discusses related technologies like compressed natural gas.
Distillation is a key separation process used in petroleum refining to separate crude oil into its various components like gasoline, kerosene, and diesel. Crude oil is first desalted and dewatered before being fed to a distillation unit where it is heated and separated based on differences in boiling points into various hydrocarbon fractions. Further refining processes like reforming, cracking, and hydrotreating are used to convert heavier fractions into lighter, more valuable products like gasoline.
Natural gas contains water that must be removed through dehydration. There are three main dehydration methods: direct cooling, adsorption, and absorption. Glycol absorption is most common, using triethylene glycol to continuously remove water down to 0.5 lb of H2O/MMSCF. Glycol dehydration has lower costs than alternatives due to easier regeneration and makeup of glycol, as well as less heat required per pound of water removed. Removing water prevents issues like reduced heating value, gas hydrate formation, and corrosion in downstream pipelines and equipment.
This document describes the process of solid bed gas dehydration. It begins with an introduction to gas dehydration and why it is needed to meet contractual water content specifications. It then covers determining the water content in a gas stream and corrections that must be made. The main part of the document discusses how solid bed dehydration systems work using adsorption onto a desiccant and provides details on the process, design considerations, example calculations, and heat requirements for regeneration. It concludes with a solved example to design a solid bed dehydration unit to treat a specific gas feed.
Crude oil production systems involve exploration, drilling, and surface production operations to extract crude oil and separate it from other fluids and gases. Surface production operations include separating the well effluent into gas, oil, and water streams using separators. The separated streams undergo further treatment, which may include dehydration to remove water, emulsion breaking, stabilization to control vapor pressure, and removal of impurities. Produced water is typically reinjected, while associated gas may be reinjected, used for power generation, or flared if not needed onsite. Wastes are also handled through treatment and disposal or reuse to protect the environment.
This document outlines the key steps in the liquefied natural gas (LNG) production process. It begins with extracting natural gas from the ground, then treating the gas to remove impurities. The treated gas is then condensed into a liquid by cooling it to -260°F through a multi-stage liquefaction process. The LNG is stored and transported in specialized cryogenic tanks on ships or trucks, then regasified back into gas form before being distributed through pipelines. The document provides details on each stage of the LNG value chain from production to regasification and discusses related technologies like compressed natural gas.
Primary processing in petroleum refineries involves distilling crude oil into basic fractions like gasoline, naphtha, and gas oil. Secondary processing further converts and improves these fractions. It includes physical processes like distillation and chemical processes like catalytic and thermal cracking to break large molecules into smaller, more valuable ones. Thermal cracking processes like visbreaking use heat to reduce the viscosity of heavy residues while delayed coking severely cracks residues into lighter products and a carbon residue of coke. The goal of secondary processing is to upgrade the crude oil fractions and maximize refinery profits.
This document provides information about the composition of crude oil, including:
1. Crude oil is composed primarily of hydrocarbon compounds like alkanes, cycloalkanes, and aromatic hydrocarbons. It also contains smaller amounts of other organic compounds containing sulfur, nitrogen, and oxygen, as well as trace metals.
2. The specific molecular composition varies between crude sources, but on average crude oil is 83-87% carbon, 10-14% hydrogen, and contains 0.1-6.0% sulfur and 0.1-2.0% nitrogen.
3. Other hydrocarbon groups found in crude include paraffins (alkanes), naphthenes (cycloalkanes), and aromatic
This document provides a preface and overview for a textbook on petroleum production engineering. It discusses how modern computer technologies have revolutionized the petroleum industry and motivated the authors to write this textbook. The textbook is intended to provide production engineers with guidelines for designing, analyzing, and optimizing petroleum production systems using computer-assisted approaches. It covers topics like well performance, artificial lift methods, and production enhancement techniques across 18 chapters in 4 parts. The preface provides details on the intended audience, topics covered, and goals of presenting engineering principles through examples and companion computer programs.
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.
Heavy oil processing involves upgrading heavy crude oils and residues through various refining processes. Heavy oils are found globally and will be an increasingly important source of crude supply. They are more viscous, contain higher concentrations of contaminants, and are more difficult and costly to produce and refine than conventional oils. Key upgrading processes include solvent deasphalting to separate heavy fractions, various hydrotreating methods to remove contaminants, and lube oil processing steps like solvent extraction, dewaxing, and hydrofinishing to produce base oils and fuels from heavy feedstocks.
The document discusses natural gas liquid (NGL) recovery processes. It describes several types of NGL recovery processes including refrigeration processes like mechanical refrigeration, self-refrigeration, and cryogenic refrigeration. It also discusses lean oil absorption, solid bed adsorption, membrane separation, and twister supersonic separation. The document provides details on different types of natural gas reservoirs and discusses various refrigeration techniques in depth. It concludes by mentioning modern NGL recovery processes are based on turbo expanders using reflux configurations.
Brief Introduction into Oil & Gas Industry by Fidan AliyevaFidan Aliyeva
This document presents five stages of the oil field life cycle, their description and some disciplines involved as well as some general facts about the oil and gas.
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 heater treaters, which are equipment used to treat crude oil emulsions by applying heat to speed up the separation of water from oil. It consists of four sections - an inlet degassing section, heating section, differential oil control chamber, and coalescing section. In the heating section, heat breaks the emulsion into separate water and oil phases. The coalescing section then uses electrodes to further coalesce any remaining water droplets from the oil. Heater treaters are typically used downstream of separators or knockouts when additional heat is needed to fully break emulsions.
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.
After crude oil is desalted and dehydrated, it is separated into fractions through distillation. However, the distilled fractions cannot be used directly and require further processing due to differences between crude oil properties and market needs. The complexity of refining processes is also due to environmental regulations that require cleaner products. Distillation involves heating crude oil to separate it based on boiling points, but the distilled fractions need additional conversion processes before they can be used or sold.
The document provides an overview of oil production processes, including:
1) Bringing well fluids to the surface, separating oil, gas and water, and preparing them for transport.
2) Key equipment at the wellhead like the casing head, tubing head and Christmas tree that control flow.
3) Common production enhancement techniques like gas lift that increase production.
4) Surface handling processes to separate, treat and test oil, gas and water before transport.
The efficiency of enhanced oil recovery method is a measure of the ability to provide greater hydrocarbon recovery than by natural depletion, at an economically attractive production rate.
Facebook Page: https://www.facebook.com/petroleumengineeringz
Blogspot: http://petroleumengineeringsociety.blogspot.com/
This document discusses different types of thermal enhanced oil recovery (EOR) techniques. It begins by introducing EOR and explaining that thermal EOR involves injecting heat into reservoirs to reduce oil viscosity and increase flow. The main thermal EOR methods covered are steam flooding, hot water flooding, and in-situ combustion. Steam flooding generates steam at the surface and injects it underground, using it to heat oil and create an artificial drive toward production wells. Hot water flooding is similar but less effective due to lower heat content. In-situ combustion recovers oil by applying heat transferred to reservoirs through conduction or convection.
In petroleum refining, the Crude Distillation Unit (CDU) (often referred to as the Atmospheric Distillation Unit) is usually the first processing equipment through which crude oil is fed. Once in the CDU, crude oil is distilled into various products, like naphtha, kerosene, and diesel, that then serve as feedstocks for all other processing units at the refinery.
Phase separation occurs in a pressure vessel called a separator that is used to separate well fluids produced from oil and gas wells into gaseous and liquid components. Separators employ mechanisms like gravity settling, centrifugal force, and baffling to separate the phases. Separator design and performance is dependent on factors like flow rates, fluid properties, presence of impurities, and foaming tendencies. Common types of separators include test separators, production separators, and low temperature separators that are used for primary separation, secondary separation, and removal of specific phases like free water.
Gas Condensate Separation Stages – Design & OptimizationVijay Sarathy
The life cycle of an oil & gas venture begins at the wellhead where subsurface engineers work their way through surveying, drilling, laying production tubing and well completions. Once a well is completed, gathering lines from each well is laid to gather hydrocarbons and transported via a main trunk line to a gas oil separation unit (GOSP) to be processed further to enhance their product value for sales. Gas condensate wells consist of natural gas which is rich in heavier hydrocarbons that are recovered as liquids in separators in field facilities or gas-oil separation plants (GOSP).
The following tutorial is aimed at demonstrating how to optimize and provide the required number of separation stages to process a gas condensate mixture and separate them into their respective vapour phase and liquid phase – termed as “Stage Separation”. Stage separation consists of laying a series of separators which operate at consecutive lower pressures to strip out vapours from the well liquids & resulting in a stabilized liquid. Prior to any hydrocarbon processing in a gas processing plant or a refinery, it is imperative to maximize the liquid recovery as well as provide a stabilized liquid hydrocarbon.
This document describes a plug flow reactor (PFR). A PFR is a model used to describe continuous chemical reactions in cylindrical systems where the residence time is the same for all fluid elements. It discusses how PFRs work with agitators along the vessel length to provide horizontal plug flow movement from feed to discharge. Advantages of PFRs include no moving parts, high conversion, and consistent product quality. Disadvantages can include poor temperature control and potential hot spots in exothermic reactions. The document compares the characteristics and performance of PFRs, continuous stirred-tank reactors (CSTRs), and batch reactors.
Primary processing in petroleum refineries involves distilling crude oil into basic fractions like gasoline, naphtha, and gas oil. Secondary processing further converts and improves these fractions. It includes physical processes like distillation and chemical processes like catalytic and thermal cracking to break large molecules into smaller, more valuable ones. Thermal cracking processes like visbreaking use heat to reduce the viscosity of heavy residues while delayed coking severely cracks residues into lighter products and a carbon residue of coke. The goal of secondary processing is to upgrade the crude oil fractions and maximize refinery profits.
This document provides information about the composition of crude oil, including:
1. Crude oil is composed primarily of hydrocarbon compounds like alkanes, cycloalkanes, and aromatic hydrocarbons. It also contains smaller amounts of other organic compounds containing sulfur, nitrogen, and oxygen, as well as trace metals.
2. The specific molecular composition varies between crude sources, but on average crude oil is 83-87% carbon, 10-14% hydrogen, and contains 0.1-6.0% sulfur and 0.1-2.0% nitrogen.
3. Other hydrocarbon groups found in crude include paraffins (alkanes), naphthenes (cycloalkanes), and aromatic
This document provides a preface and overview for a textbook on petroleum production engineering. It discusses how modern computer technologies have revolutionized the petroleum industry and motivated the authors to write this textbook. The textbook is intended to provide production engineers with guidelines for designing, analyzing, and optimizing petroleum production systems using computer-assisted approaches. It covers topics like well performance, artificial lift methods, and production enhancement techniques across 18 chapters in 4 parts. The preface provides details on the intended audience, topics covered, and goals of presenting engineering principles through examples and companion computer programs.
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.
Heavy oil processing involves upgrading heavy crude oils and residues through various refining processes. Heavy oils are found globally and will be an increasingly important source of crude supply. They are more viscous, contain higher concentrations of contaminants, and are more difficult and costly to produce and refine than conventional oils. Key upgrading processes include solvent deasphalting to separate heavy fractions, various hydrotreating methods to remove contaminants, and lube oil processing steps like solvent extraction, dewaxing, and hydrofinishing to produce base oils and fuels from heavy feedstocks.
The document discusses natural gas liquid (NGL) recovery processes. It describes several types of NGL recovery processes including refrigeration processes like mechanical refrigeration, self-refrigeration, and cryogenic refrigeration. It also discusses lean oil absorption, solid bed adsorption, membrane separation, and twister supersonic separation. The document provides details on different types of natural gas reservoirs and discusses various refrigeration techniques in depth. It concludes by mentioning modern NGL recovery processes are based on turbo expanders using reflux configurations.
Brief Introduction into Oil & Gas Industry by Fidan AliyevaFidan Aliyeva
This document presents five stages of the oil field life cycle, their description and some disciplines involved as well as some general facts about the oil and gas.
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 heater treaters, which are equipment used to treat crude oil emulsions by applying heat to speed up the separation of water from oil. It consists of four sections - an inlet degassing section, heating section, differential oil control chamber, and coalescing section. In the heating section, heat breaks the emulsion into separate water and oil phases. The coalescing section then uses electrodes to further coalesce any remaining water droplets from the oil. Heater treaters are typically used downstream of separators or knockouts when additional heat is needed to fully break emulsions.
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.
After crude oil is desalted and dehydrated, it is separated into fractions through distillation. However, the distilled fractions cannot be used directly and require further processing due to differences between crude oil properties and market needs. The complexity of refining processes is also due to environmental regulations that require cleaner products. Distillation involves heating crude oil to separate it based on boiling points, but the distilled fractions need additional conversion processes before they can be used or sold.
The document provides an overview of oil production processes, including:
1) Bringing well fluids to the surface, separating oil, gas and water, and preparing them for transport.
2) Key equipment at the wellhead like the casing head, tubing head and Christmas tree that control flow.
3) Common production enhancement techniques like gas lift that increase production.
4) Surface handling processes to separate, treat and test oil, gas and water before transport.
The efficiency of enhanced oil recovery method is a measure of the ability to provide greater hydrocarbon recovery than by natural depletion, at an economically attractive production rate.
Facebook Page: https://www.facebook.com/petroleumengineeringz
Blogspot: http://petroleumengineeringsociety.blogspot.com/
This document discusses different types of thermal enhanced oil recovery (EOR) techniques. It begins by introducing EOR and explaining that thermal EOR involves injecting heat into reservoirs to reduce oil viscosity and increase flow. The main thermal EOR methods covered are steam flooding, hot water flooding, and in-situ combustion. Steam flooding generates steam at the surface and injects it underground, using it to heat oil and create an artificial drive toward production wells. Hot water flooding is similar but less effective due to lower heat content. In-situ combustion recovers oil by applying heat transferred to reservoirs through conduction or convection.
In petroleum refining, the Crude Distillation Unit (CDU) (often referred to as the Atmospheric Distillation Unit) is usually the first processing equipment through which crude oil is fed. Once in the CDU, crude oil is distilled into various products, like naphtha, kerosene, and diesel, that then serve as feedstocks for all other processing units at the refinery.
Phase separation occurs in a pressure vessel called a separator that is used to separate well fluids produced from oil and gas wells into gaseous and liquid components. Separators employ mechanisms like gravity settling, centrifugal force, and baffling to separate the phases. Separator design and performance is dependent on factors like flow rates, fluid properties, presence of impurities, and foaming tendencies. Common types of separators include test separators, production separators, and low temperature separators that are used for primary separation, secondary separation, and removal of specific phases like free water.
Gas Condensate Separation Stages – Design & OptimizationVijay Sarathy
The life cycle of an oil & gas venture begins at the wellhead where subsurface engineers work their way through surveying, drilling, laying production tubing and well completions. Once a well is completed, gathering lines from each well is laid to gather hydrocarbons and transported via a main trunk line to a gas oil separation unit (GOSP) to be processed further to enhance their product value for sales. Gas condensate wells consist of natural gas which is rich in heavier hydrocarbons that are recovered as liquids in separators in field facilities or gas-oil separation plants (GOSP).
The following tutorial is aimed at demonstrating how to optimize and provide the required number of separation stages to process a gas condensate mixture and separate them into their respective vapour phase and liquid phase – termed as “Stage Separation”. Stage separation consists of laying a series of separators which operate at consecutive lower pressures to strip out vapours from the well liquids & resulting in a stabilized liquid. Prior to any hydrocarbon processing in a gas processing plant or a refinery, it is imperative to maximize the liquid recovery as well as provide a stabilized liquid hydrocarbon.
This document describes a plug flow reactor (PFR). A PFR is a model used to describe continuous chemical reactions in cylindrical systems where the residence time is the same for all fluid elements. It discusses how PFRs work with agitators along the vessel length to provide horizontal plug flow movement from feed to discharge. Advantages of PFRs include no moving parts, high conversion, and consistent product quality. Disadvantages can include poor temperature control and potential hot spots in exothermic reactions. The document compares the characteristics and performance of PFRs, continuous stirred-tank reactors (CSTRs), and batch reactors.
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ایمنی و بازرسی لیفتراک
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خطرات کار با لیفتراک
استفاده ایمن از لیفتراک
The document discusses various topics related to chemical reactor design including:
1. Reactor classification into homogeneous and heterogeneous types and examples like batch, continuous stirred tank, plug flow, and semi-batch reactors.
2. Factors to consider for reactor design like heat of reaction, operating temperature and pressure, and use of internal or external heating/cooling.
3. Methods for controlling temperature like adiabatic, isothermal, auto-thermal reactors.
4. Key principles of chemical equilibrium and kinetics that influence choice of process conditions.
This document discusses various types of chemical reactors. It begins by defining a reactor as a vessel designed to contain chemical reactions. It then covers basic design principles like reaction type and factors influencing reaction rate. It describes several reactor types classified by mode of operation (batch, continuous, semi-batch), end use application (polymerization, bio, electrochemical), number of phases, and whether a catalyst is used. Specific reactor types covered include CSTR, plug flow, tubular flow, and fixed bed. The document also discusses catalysis, including homogeneous vs heterogeneous catalysts and common catalyst types.