Crude Production & Oil Treatment Facilities Tronix
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II.1 Crude Production & Oil Treatment Facilities
II. Fundamentals of Oil & Gas Production & processing, Main equipment/ Eng.Documentation
Crude Production & Oil Treatment Facilities
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OIL & GAS FACILITIES
Oil Facilities
Petroleum Refining
Crude Production/ Treatment Facilities
Gas Facilities
Gas Production/ Treatment/ Processing Facilities
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Basics Of Crude Oil Crude oils are complex mixtures containing many different hydrocarbon compounds that vary in appearance and composition from one oil field to another. Crude oils range in consistency from water to tar-like solids, and in color from clear to black.
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Basics Of Crude Oil An "average" crude oil contains about: 84% 14%
Carbon Hydrogen
1%-3% less than 1%
Sulfur each of Nitrogen, Oxygen, Metals, and Salts
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Basics Of Crude Oil The properties of hydrocarbons depend on the number and arrangement of the carbon and hydrogen atoms in the molecules.
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Basics Of Hydrocarbon Chemistry Hydrocarbons containing up to four carbon atoms are usually gases. Those with 5 to 19 carbon atoms are usually liquids, and those with 20 or more are solids.
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Basics Of Hydrocarbon Chemistry Crude Oil Consists Mainly From Hydrocarbon Compounds Non Hydrocarbon Compounds
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Basics Of Hydrocarbon Chemistry Three Principal Groups or Series of Hydrocarbon Compounds that Occur Naturally in Crude Oil a. Paraffins. b. Aromatics c. Naphthenes
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Nonhydrocarbons Sulfur Compounds: (Elemental Sulfur, Mercaptans, Sulfides, Disulfides, Thiophenes) Oxygen Compounds: (Phenols, Ketones, And Carboxylic Acids) Nitrogen Compounds: (Ammonia And Cyanides)
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Nonhydrocarbons Trace Metals: (Nickel, Iron, And Vanadium ) Salts (Sodium Chloride, Magnesium Chloride, And Calcium Chloride, NH44Cl ) Carbon Dioxide Naphthenic Acids
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Crude Oil Properties Gravity, °API (20 - 45) Sulfur Content (0.1 – 5 WT%) Pour Point The lower the pour point the lower the paraffin content and the greater the content of aromatics.
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Crude Oil Properties Salt Content: If the salt content of the crude, when expressed as Nacl, is greater than 10 lb/ 1,000 bbl, it is generally necessary to desalt the crude before processing.
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Crude Oil Properties Distillation Boiling Range: The boiling range of the crude gives an indication of the quantities of the various products present. The most useful type of distillation is known as a true boiling point (TBP).
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Crude Oil Properties Metals Content: Quantities of some of these metals (nickel, vanadium, and copper) can severely affect the activities of catalysts and result in a lower-value product distribution.
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Classification Of Crude Oil Paraffin Base Crudes: Crudes that consist of more than 50% of paraffins. Naphthene Base Crudes: These crudes consist of more than 50% of Cyclic (Naphthenic)compounds. Asphalt Base Crudes: These crudes contain a very high percentage of aromatics. Mixed Base Crudes: These crude contain large quantities of both paraffinic and naphthenic compounds.
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Crude Oil Water Content Free water Emulsified water
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Free Water If water droplets are collected together and settle to the bottom of a sample within five minutes, they are called free water
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Emulsified Water All water remaining in the crude after the free water is allowed to settle out, is considered to be in the emulsified state and is to be removed by treating equipment
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Emulsified Water Treatment Reasons for water-in oil Emulsion: 1- Sand, carbon, carbonates, sulphates and many other organic and inorganic materials found in well fluid act as an emulsifying agent.
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Emulsified Water Treatment Reasons for water-in oil Emulsion 2- Agitation provided by a downhole pump, gas lift valves, or tubing restrictions; the turbulence caused by the pressure drop across the choke is the primary source of agitation for emulsion formation.
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Factors Affecting Emulsion Breakdown Differential Density The greater the difference in density between the water and oil phases, the easier the separation. Viscosity Reduction in viscosity of the oil phase reduces the friction encountered by the water particles in moving through the oil phase and thus promotes separation of the phases.
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3- Interfacial Tension Anything that lowers the interfacial tension will serve as an aid to separation. Addition of chemicals is the method normally used in oil field emulsion treating to accomplish this end.
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4- Water Drop Size The smaller the average dispersed water particle size the more difficult will be the separation. Ultimately, settling of the water droplet from the oil must be accomplished by gravity settling, so the smaller the drop, and the slower the separation.
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5- Water Salinity The higher the salinity, the greater the density of the produced water and the greater the difference in the density of the produced water and oil phases. As mentioned previously this will tend to make the separation easier.
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5- Water Salinity (cont’d) Small amounts of salt (or other dissolved solids) in the water phase will appreciably lower the interfacial tension. Again, as mentioned previously, this will decrease the difficulty of separating the two phases. To some degree this phenomenon explains the difficulty of treating water-oil emulsions formed from soft water.
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6- Water Volume Percent More stable emulsions are created when only very small amounts of water are present.
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7- Emulsifier Agents Emulsifier Agents: (i.e. Sand, Carbon, Carbonates, Sulphates And Many Other Organic And Inorganic Materials) Emulsifying agents increase the interfacial tension between the phases. However, this property is controllable by chemical action .
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8- Age Of Emulsion As emulsions age they become more stable and separation difficulties increase.
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Crude Production & treatment Facilities Crude inlet manifold and receiving facilities. Separation ( Production &Test separator) Crude oil Treatment (Dehydration &Desalting) and stabilization
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Inlet Manifold & Receiving Facilities Purpose: To receive different inlet streams coming from different sources (wells) and guarantee a uniform organized & steady state feed to the production facilities.
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Separation Separation of gases from liquid can be done in gravity separators pressure vessels that separate a mixed phase stream into gas and liquid phases that are relatively free of each other.
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A primary gas / liquid separation section with an inlet diverter to remove the bulk of the liquid from the gas. A gravity – settling section providing adequate retention time so that proper settling may take place to separate oil from free water.
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A mist extractor at the gas outlet to capture entrained droplets or those too small to settle by gravity. Proper pressure and liquid-level controls.
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Gravity separators
A Typical scheme of a horizontal threephase separator
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Crude Oil Treatment Facilities Purpose To remove salt present in the crude in the form of dissolved or suspended salt crystals in the free water or in the emulsified water within the crude oil. To remove suspended solids from the crude oil i.e. very fine sand, clay, soil particles, iron oxide and iron sulfide particles from pipelines, tanks, or tankers, and other contaminates picked up in transit or production.
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Crude Oil Treatment Advantages Of Treatment Processes Prevents salt disposition on H.T. equipment surface, which means prevent fouling. Prevents acids formation caused by decomposition of chloride salts consequently prevent corrosion.
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Crude Oil Treatment Advantages Of Treatment Processes Prevents catalyst deactivation caused by metals present in the crude so preventing poisoning. To meet Pipeline / marketing requirements.
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Treatment Of Salt In Crude Oil Whenever crude oil is produced in direct association with saline waters originally in place in oil-bearing strata, that oil will contain salt
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Salt In Crude Oil Salt As Crystals Salt In Solution
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Salt In Crude Oil Salt As Crystals It is possible for salt to exist as crystals in crude oil, but this situation is the exception rather than the general rule. In relatively small quantities, crystals of sulphate are sometimes found. Salt in oil rarely exists as solid crystals.
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Salt In Solution The more common occurrence is to find salt existing in solution in the remnant brine associated with the oil. This remnant brine is only the water that cannot be removed from the crude by ordinary treating processes; it is the water portion that is measured and reported as basic sediment and water (BS&W).
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Salt In Solution This remnant water exists in the crude oil as a general dispersion or in fine droplets highly stabilized by emulsifying agents. The salt content of an oil sample of given volume is that amount of salt in solution within the brine dispersed; In the oil.
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The soluble mineral salts contained in water from most of the oil fields of the world are predominantly chlorides of sodium, calcium and magnesium.
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Amount Of Salt In Crude Unit Of Measurement The quantitative unit of salt measurement is usually pounds of salt, expressed as equivalent sodium chloride per thousand barrels of oil, (P.T.B.). This quantity may range anywhere from ten to several hundred pounds per thousand barrels .
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Controlling Amount Of Salt In Crude In some cases, control of the salt in the crude can be accomplished by control of the remnant water in the crude. However, the ultimate objective of desalting systems is the reduction of the dissolved solids content of the remnant water through the following: -
Free water removal. Emulsion breaking and separation of released water down to a level of 0.2 % or less.
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Desalting Processes Of Crude Oil When Salt Must Be Removed? The amount of salt that refineries will tolerate in crude will vary, but in general some sort of desalting treatment is indicated if the salt content of the crude is greater than 15 to 25 pounds of salt per 1000 barrels of crude. When the concentration of salts in crude petroleum exceeds this level, the salty crude will cause severe problems during the refining process.
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Certain salts such as calcium and magnesium chloride are destructive to refinery equipment by producing corrosive compounds under the high temperatures of the refining process. Also, any mineral residues in the crude tend to deposit somewhere in the refinery equipment. Such deposits initiate coking effects and form finally coke that is difficult to be removed by usual clean-out processes.
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Emulsion Treatment Processes 1 - Chemical Treatment 2 - Heaters 3 - Gunbarrel Treaters 4 - Heater-treaters 5 - Chemelectric Treaters
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Chemical Treatment Purpose: The purpose of treating chemicals is to act on and destroy or rupture the tough film surrounding the water droplets and induce coalescence so that the oil and water will separate rapidly.
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Emulsion Treating Chemicals Practically all-modern emulsion treating chemicals are more soluble in oil than in water, with the exception of a few chemicals made for reverse emulsions. These latter are essentially water-soluble.
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Emulsion Treating Chemicals There is no universal chemical, which will break all emulsions equally well. Determining the correct chemical to use is generally done by representatives of the treating chemical manufacturers. The chemical should be added as continuously as possible during the entire production period and at a rate related to the production rate.
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Emulsion Treating Chemicals Where a gas/oil separator is being used, the ideal location for chemical injection is at the manifold before the fluid enters the separator. If a separator is not being used, chemical should be added at least 200 feet from the treater, and farther away if possible.
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Heaters Direct Heater: In direct heater the crude is passed through a coil of pipe that is exposed to the direct flame in the firebox of a furnace, or to the hot gases resulting from combustion in a furnace. Direct heaters are quick, efficient, and initial cost is relatively low. On the other hand, it is wasteful, dangerous, and requires further constant supervision.
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Heaters Indirect Heater In the indirect heater, Oil is flowed through tubes, which are immersed in water, which in turn is heated by a fire-tube. An indirect heater has the advantage of maintaining a constant temperature throughout and over a long period of time, Hot spots are not as likely to occur.
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Heaters Indirect Heater The indirect heater has the disadvantage of requiring several hours to heat after it has been out of service, making it impossible to treat oil immediately.
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Gunbarrel Heaters The oldest means used for oil treating. They are large tanks usually having centre flumes extending from two to five feet off bottom to six to 12 feet above the top of the tank.
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Gunbarrel Heaters Low-pressure vertical flow Treater, of large diameter, is called "Gunbarrel". Most Gunbarrels are unheated, though it is possible to provide heat by heating the incoming stream external to the tank, installing heat coils in the tank, or circulating the water to an external heater in a closed loop.
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Heated Gunbarrel Emulsion treater
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Heated Gunbarrel Emulsion treater
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Heater- Treaters Heater-treaters have the following advantages as compared to Gunbarrel that use heaters: Advantages: Lower initial cost Lower installation cost Greater flexibility Greater overall efficiency
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Heater- Treaters Heater-treaters have the following disadvantages as compared to Gunbarrel that use heaters: Disadvantages: More complicated More sensitive to chemicals.
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Heater - Treaters Liquids enters in the upper section of vessel releases entrained gas if found, off-gas may be vented, delivered into low-pressure gas system or compressed for delivery into a higher-pressure gas system. The emulsion (Oil +Water) moves through a tube to the lower section of the vessel and emerges to move in proximity to a warming coil usually called a "firebox" or "fire tube heater“. INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
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Heater - Treaters
This heating, usually to a temperature ranging from 45ooC to 200 ooC expedites coalescence and water gravitates to the bottom of the vessel. Oil rises to an appropriate section of the vessel where it may be emptied to storage.
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Horizontal Heater-Treater INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
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Horizontal Heater-Treater INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
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Vertical Treater
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Vertical Treater
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Electrostatic Treater (Chemelectric Heater- Treater) Chemelectric treaters use some combination of heat, electricity, chemicals, retention time and coalescence to separate oil and water.
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Chemelectric Treater This is a process that increases in economic attractiveness directly with liquid volume to be handled, but it requires electricity to operate. Chemelectric Treater is most attractive when large liquid volumes are treated.
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Chemelectric Operating Principle Chemelectric Treater cylindrical vessel.
is
usually
a
horizontal
Emulsion enters the treater and passes upward through a water bath that segregates as much water as will "fall out" of the oil.
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Chemelectric Operating Principle As the remaining emulsion rises through an electrically charged grid, the drops become electrified, or ionized. The efficiency and rate of coalescing are greatly accelerated by this electric field after the emulsifying agent is ruptured or displaced to expose the surface of the water droplet.
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Chemelectric Operating Principle water drops in oil are attracted to each other if an electric field of sufficiently high gradient is imposed on the system. This method of forced collision is called electrostatic coalescing. As the water drops collide, they combine to grow in size until the drops the water section of the vessel and be drained.
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Chemelectric Requires Less Heat Because of electrostatic coalescing, this method of coalescing usually allows this treating process to take place at lower temperatures than those of conventional treaters. Use of lower temperatures is directly reflected in reduced fuel costs.
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ElectroStatic Desalting
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Single Stage Electrical Desalter
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Single Stage Electrical Desalter
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Single Stage Electrical Desalter
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Two Stages Electrical Desalter
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Two Stages Electrical Desalter
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Fresh" Water Addition (Dilution By Water)" From a theoretical standpoint, quantities of water in the range of 1 to 3 percent are usually adequate; however, from a practical standpoint, the fresh water is added in minimum quantities of 5 to 7 percent. The following are typical operating conditions: API
W VOL%
API>40 30<API<40 API<30
3-4 4-7 7 – 10
TEMP °C (°F) 115 - 125 C (240-260 F) 125 - 140 C (260-280 F) 140 - 150 C (280-300 F)
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Crude Production & Oil Treatment Facilities
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OIL & GAS FACILITIES
Oil Facilities
Petroleum Refining
Crude Production/ Treatment Facilities
Gas Facilities
Gas Production/ Treatment/ Processing Facilities
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Basics Of Crude Oil Crude oils are complex mixtures containing many different hydrocarbon compounds that vary in appearance and composition from one oil field to another. Crude oils range in consistency from water to tar-like solids, and in color from clear to black.
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Basics Of Crude Oil An "average" crude oil contains about: 84% 14%
Carbon Hydrogen
1%-3% less than 1%
Sulfur each of Nitrogen, Oxygen, Metals, and Salts
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Basics Of Crude Oil The properties of hydrocarbons depend on the number and arrangement of the carbon and hydrogen atoms in the molecules.
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Basics Of Hydrocarbon Chemistry Hydrocarbons containing up to four carbon atoms are usually gases. Those with 5 to 19 carbon atoms are usually liquids, and those with 20 or more are solids.
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Basics Of Hydrocarbon Chemistry Crude Oil Consists Mainly From Hydrocarbon Compounds Non Hydrocarbon Compounds
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Basics Of Hydrocarbon Chemistry Three Principal Groups or Series of Hydrocarbon Compounds that Occur Naturally in Crude Oil a. Paraffins. b. Aromatics c. Naphthenes
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Nonhydrocarbons Sulfur Compounds: (Elemental Sulfur, Mercaptans, Sulfides, Disulfides, Thiophenes) Oxygen Compounds: (Phenols, Ketones, And Carboxylic Acids) Nitrogen Compounds: (Ammonia And Cyanides)
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Nonhydrocarbons Trace Metals: (Nickel, Iron, And Vanadium ) Salts (Sodium Chloride, Magnesium Chloride, And Calcium Chloride, NH44Cl ) Carbon Dioxide Naphthenic Acids
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Crude Oil Properties Gravity, °API (20 - 45) Sulfur Content (0.1 – 5 WT%) Pour Point The lower the pour point the lower the paraffin content and the greater the content of aromatics.
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Crude Oil Properties Salt Content: If the salt content of the crude, when expressed as Nacl, is greater than 10 lb/ 1,000 bbl, it is generally necessary to desalt the crude before processing.
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Crude Oil Properties Distillation Boiling Range: The boiling range of the crude gives an indication of the quantities of the various products present. The most useful type of distillation is known as a true boiling point (TBP).
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Crude Oil Properties Metals Content: Quantities of some of these metals (nickel, vanadium, and copper) can severely affect the activities of catalysts and result in a lower-value product distribution.
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Classification Of Crude Oil Paraffin Base Crudes: Crudes that consist of more than 50% of paraffins. Naphthene Base Crudes: These crudes consist of more than 50% of Cyclic (Naphthenic)compounds. Asphalt Base Crudes: These crudes contain a very high percentage of aromatics. Mixed Base Crudes: These crude contain large quantities of both paraffinic and naphthenic compounds.
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Crude Oil Water Content Free water Emulsified water
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Free Water If water droplets are collected together and settle to the bottom of a sample within five minutes, they are called free water
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Emulsified Water All water remaining in the crude after the free water is allowed to settle out, is considered to be in the emulsified state and is to be removed by treating equipment
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Emulsified Water Treatment Reasons for water-in oil Emulsion: 1- Sand, carbon, carbonates, sulphates and many other organic and inorganic materials found in well fluid act as an emulsifying agent.
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Emulsified Water Treatment Reasons for water-in oil Emulsion 2- Agitation provided by a downhole pump, gas lift valves, or tubing restrictions; the turbulence caused by the pressure drop across the choke is the primary source of agitation for emulsion formation.
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Factors Affecting Emulsion Breakdown Differential Density The greater the difference in density between the water and oil phases, the easier the separation. Viscosity Reduction in viscosity of the oil phase reduces the friction encountered by the water particles in moving through the oil phase and thus promotes separation of the phases.
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3- Interfacial Tension Anything that lowers the interfacial tension will serve as an aid to separation. Addition of chemicals is the method normally used in oil field emulsion treating to accomplish this end.
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4- Water Drop Size The smaller the average dispersed water particle size the more difficult will be the separation. Ultimately, settling of the water droplet from the oil must be accomplished by gravity settling, so the smaller the drop, and the slower the separation.
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5- Water Salinity The higher the salinity, the greater the density of the produced water and the greater the difference in the density of the produced water and oil phases. As mentioned previously this will tend to make the separation easier.
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5- Water Salinity (cont’d) Small amounts of salt (or other dissolved solids) in the water phase will appreciably lower the interfacial tension. Again, as mentioned previously, this will decrease the difficulty of separating the two phases. To some degree this phenomenon explains the difficulty of treating water-oil emulsions formed from soft water.
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6- Water Volume Percent More stable emulsions are created when only very small amounts of water are present.
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7- Emulsifier Agents Emulsifier Agents: (i.e. Sand, Carbon, Carbonates, Sulphates And Many Other Organic And Inorganic Materials) Emulsifying agents increase the interfacial tension between the phases. However, this property is controllable by chemical action .
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8- Age Of Emulsion As emulsions age they become more stable and separation difficulties increase.
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Crude Production & treatment Facilities Crude inlet manifold and receiving facilities. Separation ( Production &Test separator) Crude oil Treatment (Dehydration &Desalting) and stabilization
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Inlet Manifold & Receiving Facilities Purpose: To receive different inlet streams coming from different sources (wells) and guarantee a uniform organized & steady state feed to the production facilities.
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Separation Separation of gases from liquid can be done in gravity separators pressure vessels that separate a mixed phase stream into gas and liquid phases that are relatively free of each other.
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A primary gas / liquid separation section with an inlet diverter to remove the bulk of the liquid from the gas. A gravity – settling section providing adequate retention time so that proper settling may take place to separate oil from free water.
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A mist extractor at the gas outlet to capture entrained droplets or those too small to settle by gravity. Proper pressure and liquid-level controls.
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Gravity separators
A Typical scheme of a horizontal threephase separator
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Crude Oil Treatment Facilities Purpose To remove salt present in the crude in the form of dissolved or suspended salt crystals in the free water or in the emulsified water within the crude oil. To remove suspended solids from the crude oil i.e. very fine sand, clay, soil particles, iron oxide and iron sulfide particles from pipelines, tanks, or tankers, and other contaminates picked up in transit or production.
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Crude Oil Treatment Advantages Of Treatment Processes Prevents salt disposition on H.T. equipment surface, which means prevent fouling. Prevents acids formation caused by decomposition of chloride salts consequently prevent corrosion.
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Crude Oil Treatment Advantages Of Treatment Processes Prevents catalyst deactivation caused by metals present in the crude so preventing poisoning. To meet Pipeline / marketing requirements.
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Treatment Of Salt In Crude Oil Whenever crude oil is produced in direct association with saline waters originally in place in oil-bearing strata, that oil will contain salt
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Salt In Crude Oil Salt As Crystals Salt In Solution
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Salt In Crude Oil Salt As Crystals It is possible for salt to exist as crystals in crude oil, but this situation is the exception rather than the general rule. In relatively small quantities, crystals of sulphate are sometimes found. Salt in oil rarely exists as solid crystals.
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Salt In Solution The more common occurrence is to find salt existing in solution in the remnant brine associated with the oil. This remnant brine is only the water that cannot be removed from the crude by ordinary treating processes; it is the water portion that is measured and reported as basic sediment and water (BS&W).
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Salt In Solution This remnant water exists in the crude oil as a general dispersion or in fine droplets highly stabilized by emulsifying agents. The salt content of an oil sample of given volume is that amount of salt in solution within the brine dispersed; In the oil.
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The soluble mineral salts contained in water from most of the oil fields of the world are predominantly chlorides of sodium, calcium and magnesium.
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Amount Of Salt In Crude Unit Of Measurement The quantitative unit of salt measurement is usually pounds of salt, expressed as equivalent sodium chloride per thousand barrels of oil, (P.T.B.). This quantity may range anywhere from ten to several hundred pounds per thousand barrels .
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Controlling Amount Of Salt In Crude In some cases, control of the salt in the crude can be accomplished by control of the remnant water in the crude. However, the ultimate objective of desalting systems is the reduction of the dissolved solids content of the remnant water through the following: -
Free water removal. Emulsion breaking and separation of released water down to a level of 0.2 % or less.
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Desalting Processes Of Crude Oil When Salt Must Be Removed? The amount of salt that refineries will tolerate in crude will vary, but in general some sort of desalting treatment is indicated if the salt content of the crude is greater than 15 to 25 pounds of salt per 1000 barrels of crude. When the concentration of salts in crude petroleum exceeds this level, the salty crude will cause severe problems during the refining process.
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Certain salts such as calcium and magnesium chloride are destructive to refinery equipment by producing corrosive compounds under the high temperatures of the refining process. Also, any mineral residues in the crude tend to deposit somewhere in the refinery equipment. Such deposits initiate coking effects and form finally coke that is difficult to be removed by usual clean-out processes.
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Emulsion Treatment Processes 1 - Chemical Treatment 2 - Heaters 3 - Gunbarrel Treaters 4 - Heater-treaters 5 - Chemelectric Treaters
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Chemical Treatment Purpose: The purpose of treating chemicals is to act on and destroy or rupture the tough film surrounding the water droplets and induce coalescence so that the oil and water will separate rapidly.
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Emulsion Treating Chemicals Practically all-modern emulsion treating chemicals are more soluble in oil than in water, with the exception of a few chemicals made for reverse emulsions. These latter are essentially water-soluble.
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Emulsion Treating Chemicals There is no universal chemical, which will break all emulsions equally well. Determining the correct chemical to use is generally done by representatives of the treating chemical manufacturers. The chemical should be added as continuously as possible during the entire production period and at a rate related to the production rate.
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Emulsion Treating Chemicals Where a gas/oil separator is being used, the ideal location for chemical injection is at the manifold before the fluid enters the separator. If a separator is not being used, chemical should be added at least 200 feet from the treater, and farther away if possible.
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Heaters Direct Heater: In direct heater the crude is passed through a coil of pipe that is exposed to the direct flame in the firebox of a furnace, or to the hot gases resulting from combustion in a furnace. Direct heaters are quick, efficient, and initial cost is relatively low. On the other hand, it is wasteful, dangerous, and requires further constant supervision.
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Heaters Indirect Heater In the indirect heater, Oil is flowed through tubes, which are immersed in water, which in turn is heated by a fire-tube. An indirect heater has the advantage of maintaining a constant temperature throughout and over a long period of time, Hot spots are not as likely to occur.
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Heaters Indirect Heater The indirect heater has the disadvantage of requiring several hours to heat after it has been out of service, making it impossible to treat oil immediately.
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Gunbarrel Heaters The oldest means used for oil treating. They are large tanks usually having centre flumes extending from two to five feet off bottom to six to 12 feet above the top of the tank.
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Gunbarrel Heaters Low-pressure vertical flow Treater, of large diameter, is called "Gunbarrel". Most Gunbarrels are unheated, though it is possible to provide heat by heating the incoming stream external to the tank, installing heat coils in the tank, or circulating the water to an external heater in a closed loop.
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Heated Gunbarrel Emulsion treater
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Heated Gunbarrel Emulsion treater
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Heater- Treaters Heater-treaters have the following advantages as compared to Gunbarrel that use heaters: Advantages: Lower initial cost Lower installation cost Greater flexibility Greater overall efficiency
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Heater- Treaters Heater-treaters have the following disadvantages as compared to Gunbarrel that use heaters: Disadvantages: More complicated More sensitive to chemicals.
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Heater - Treaters Liquids enters in the upper section of vessel releases entrained gas if found, off-gas may be vented, delivered into low-pressure gas system or compressed for delivery into a higher-pressure gas system. The emulsion (Oil +Water) moves through a tube to the lower section of the vessel and emerges to move in proximity to a warming coil usually called a "firebox" or "fire tube heater“. INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
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Heater - Treaters
This heating, usually to a temperature ranging from 45ooC to 200 ooC expedites coalescence and water gravitates to the bottom of the vessel. Oil rises to an appropriate section of the vessel where it may be emptied to storage.
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Horizontal Heater-Treater INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
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Horizontal Heater-Treater INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
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Vertical Treater
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Vertical Treater
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Electrostatic Treater (Chemelectric Heater- Treater) Chemelectric treaters use some combination of heat, electricity, chemicals, retention time and coalescence to separate oil and water.
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Chemelectric Treater This is a process that increases in economic attractiveness directly with liquid volume to be handled, but it requires electricity to operate. Chemelectric Treater is most attractive when large liquid volumes are treated.
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Chemelectric Operating Principle Chemelectric Treater cylindrical vessel.
is
usually
a
horizontal
Emulsion enters the treater and passes upward through a water bath that segregates as much water as will "fall out" of the oil.
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Chemelectric Operating Principle As the remaining emulsion rises through an electrically charged grid, the drops become electrified, or ionized. The efficiency and rate of coalescing are greatly accelerated by this electric field after the emulsifying agent is ruptured or displaced to expose the surface of the water droplet.
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Chemelectric Operating Principle water drops in oil are attracted to each other if an electric field of sufficiently high gradient is imposed on the system. This method of forced collision is called electrostatic coalescing. As the water drops collide, they combine to grow in size until the drops the water section of the vessel and be drained.
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Chemelectric Requires Less Heat Because of electrostatic coalescing, this method of coalescing usually allows this treating process to take place at lower temperatures than those of conventional treaters. Use of lower temperatures is directly reflected in reduced fuel costs.
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ElectroStatic Desalting
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Single Stage Electrical Desalter
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Single Stage Electrical Desalter
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Single Stage Electrical Desalter
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Two Stages Electrical Desalter
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II.1 Crude Production & Oil Treatment Facilities
II. Fundamentals of Oil & Gas Production & processing, Main equipment/ Eng.Documentation
Two Stages Electrical Desalter
INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
82
II.1 Crude Production & Oil Treatment Facilities
II. Fundamentals of Oil & Gas Production & processing, Main equipment/ Eng.Documentation
INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
83
II.1 Crude Production & Oil Treatment Facilities
II. Fundamentals of Oil & Gas Production & processing, Main equipment/ Eng.Documentation
Fresh" Water Addition (Dilution By Water)" From a theoretical standpoint, quantities of water in the range of 1 to 3 percent are usually adequate; however, from a practical standpoint, the fresh water is added in minimum quantities of 5 to 7 percent. The following are typical operating conditions: API
W VOL%
API>40 30<API<40 API<30
3-4 4-7 7 – 10
TEMP °C (°F) 115 - 125 C (240-260 F) 125 - 140 C (260-280 F) 140 - 150 C (280-300 F)
INTRODUCTORY MODULE TO THE OIL & GAS INDUSTRY
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