Untitled record

full description

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The current disclosure relates to a technology for a gas oil separation plant

(GOSP). Specifically, the disclosure relates to combined processes of crude oil desalting, dehydration, sweetening and stabilization for the production of crude oil.

<p dir="rtl">5 GOSP systems and processes a degree of proficiency.</p>

In general, GOSP is a continuous separation process used for crude oil refining that includes a high pressure production trap (HPT), a low pressure production trap (LPPT), a low pressure LPDT gas separation reservoir. degassing tank), a drying unit, a degassing unit consisting of a first and a second stage, and a water/oil separation plant.

WOSEP (separation plant), stabilizing column, centrifugal pumps, heat exchangers,

And my legs. In a GOSP, the pressure is usually reduced in several stages to allow the regulated separation of volatile components, such as trapped vapors. The objectives of GOSP include achieving a maximum rate of liquid recovery with a stable oil after it has been separated from the gas, and water separated from the gases 15 and oil. Or in other words, from the grounds of the GOSP plant to remove water, salt, and hydrocarbon gases

Volatile from wet crude oil after it was obtained from a reservoir carrying hydrocarbons.

However, a significant pressure drop in a single separator causes flash evaporation, resulting in unbalanced and security risks. For this, in the GOSP station according to the previous art, many relays and modules are required. Figure 1 shows three relays in GOSP systems and processes in the prior art. In a first stage, gas, crude oil and free water are separated. In a second stage, the water removes (dries) the oil

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Crude and desalinize it to separate the emulsified water and salt in accordance with the specifications of a certain base sediment and BSW (basic sediment and water). In a third stage, the crude oil is balanced and desalted to meet H2S (Hydrogen sulfide) specifications and vapor pressure according to Reid Vapor Pressure (RVP) Reid specifications (RVP).

<p dir="rtl">5 US Patent No. 2011120913 relates to a method and apparatus for determining statistically optimal desalination parameter settings for the lowest cost removal of metals, amines, and other contaminants from crude oil through electrostatic coupling.</p>

US Patent No. 2007267325 relates to a process for treating (purifying) crude oil (produced from a well, i.e. producing crude oil) and an apparatus for its implementation, and a process for separating a water emulsion in a hydrocarbon oil

<p dir="rtl">ten and device to implement it.</p>

US Patent No. 1247500 relates to a swinging rack or hook device and its primary purpose is to create a hook that allows the free movement of the swing while at the same time suppressing noise.

A gas oil separation plant (GOSP) is often operated to meet the following specifications: (1) a salt concentration of not more than about 4.5 kg of

<p dir="rtl">fifteen salt/159,000 liters; (2) basic sediment and water</p>

(BSW) Not more than 0.3% by volume (V%); (3) an H2S content (concentration) less than about 60 ppm either in an oil stabilization tower (or degassing vessels in the case of sweet crude (no sulfur); and (4) maximum vapor pressure according to the Reid Vapor (RVP) method Reid Pressure (RVP) specifications are about 0.05 MPa and the maximum vapor pressure

<p dir="rtl">twenty The actual TVP (true vapor pressure) is about 0.09 MPa at 54.4 °C. Certain characteristics of traditional GOSP systems and processes are further explained with respect to Figure 2.</p>

General description of the invention

The present disclosure describes systems and process for a gas oil separation plant

GOSP (separation plant) integrated to meet the specifications of crude oil exports and use units

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Less treatment than the GOSP plant according to the previous art. By integrating desalination, drying, desalting and stabilizing processes and applying them concurrently in pre-existing gas-oil separation vessels, systems and processes are obtained with a degree of uniquely and unexpectedly efficient. The systems and methods, according to the current disclosure, can meet the specifications of crude oil exports, including:

<p dir="rtl">5 (1) Salt concentration not exceeding about 4.5 kilograms / 159,000 liters; (2) BSW content No</p>

greater than 0.3% by volume; (3) Hydrogen sulfide H2S content (concentration) less than about 60 ppm either in an oil stabilization tower (or degassing vessels in the case of sweet crude); and (4) the maximum and vapor pressure according to the Reid method (RVP) Reid Vapor Pressure (RVP) specifications about 0.05 MPa and the maximum pressure

<p dir="rtl">ten TVP is about 0.09 MPa absolute at 54.4 °C.</p>

Models of systems and methods according to the disclosed invention ensure the ability to separate and stabilize crude oils with “tight” emulsions and increased water cut-off points that current GOSP systems and methods are unable to separate and stabilize. Or in other words, conventional desalination units can treat crude oils with water cutoffs between about 30% and about 35%. However, current detection models efficiently handle oils

<p dir="rtl">fifteen Rough to remove water when the water cutoff is greater than about 35%. Crude oil with a tight emulsion typically appears in medium to heavy crude oils that have API numbers of less than about 29. The specific gravity of an oil is typically used in API as a measure of oil quality. A higher API value indicates a lighter oil and therefore a higher market value.</p>

<p dir="rtl">twenty The water cutoff in oil production refers to the total volume of water in the crude oil stream divided by the total volume of crude oil and water. In other words, the percentage of water cutoff is the total water volumetric flow rate divided by the oil and water volumetric flow rate multiplied by 100. The water cutoff generally increases with the age of the oil well. For example, water cut-off at the beginning of a well's life is about 0%, but with the age of a well, water cutoff can reach approximately</p>

25 to 100%.

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In certain embodiments, systems and methods are presented to treat wet, acidic, unstable crude oil to meet shipping and transport specifications by subjecting the crude oil to processes of drying, desalination, stabilization and desalination simultaneously. In some embodiments, three conventional stages of crude oil treatment can be performed in only one stage. In some embodiments, crude oil desalination, drying, and desalination processes are combined

5 and installed in the existing separation containers on three phases inside the GOSP station. The drying of the crude oil involves separating the formation water, while the desalination process involves washing the crude with regenerated water in addition to or instead of recycling the water to comply with the required salt content and BSW specifications. Recycled water is used in the systems and methods disclosed to reduce the amount of regenerated wash water required.

<p dir="rtl">ten The crude desalination process involves the removal of dissolved H2S from crude oil in compliance with specifications in a range of about</p>

<p dir="rtl">10- 60 ppm by weight, while crude stabilization involves removing light products from crude oil, mostly C1-C4 hydrocarbons to reduce TVP pressure to less than about 0.09 MPa absolute at 54.4 °C below atmospheric pressure, In other words, no fumes rise quickly under weather conditions, which makes it safe to transport and ship.</p>

<p dir="rtl">fifteen The ore balance can be stabilized if the ore is heated in several stages of separation cylinders operating under increased temperatures and reduced pressure.</p>

Therefore, an integrated system for a gas-oil separation plant is disclosed in this document, which includes: a crude oil input feed stream; A high pressure HPPT production trap, in which the HPPT tank is connected via fluid to the oil inlet feed stream.

<p dir="rtl">twenty crude, wherein the HPPT container includes an inlet mixer that mixes the crude inlet feed stream with an additional fluid well, a set of insulated electrostatic electrodes, and a fence; a low pressure production trap LPPT container, where the LPPT container is fluidly compared to the HPPT container; Where the LPPT housing includes an input mixer that finely mixes the LPPT input feed stream, a set of electrodes</p>

<p dir="rtl">25 electrostatic insulated, fencing; Low pressure . gas removal storage</p>

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An LPDT degassing tank, where the LPDT reservoir is fluidly coupled to an LPPT container, and where the LPDT reservoir includes an inlet mixing device that mixes the LPDT input feed stream well, a set of insulated electrostatic electrodes, and a fence; Low Pressure Degassing Tank (LPDT), where the LPDT tank is attached to the LPPT container, and where the LPDT tank includes a mixing device

<p dir="rtl">5 Fine mixing input LPDT stock input input, set of insulated electrodes, and enclosure; a first heat exchanger, where the first heat exchanger is placed through the fluid between the HPPT container and the LPPT container and connected via the fluid to both the HPPT and LPPT containers, and where the first heat exchanger heats the input LPPT feed stream; and a second heat exchanger, wherein the second heat exchanger is held in place via the fluid between the LPPT container and the LPDT tank and coupled via</p>

<p dir="rtl">ten The fluid in both the LPPT container and the LPDT stockpile, and where the second heat exchanger heats the LPDT stock input feed stream; a recycled water stream from the LPPT container, where the recycled water stream from the LPPT container supplies recycled water from the LPPT container to be mixed with the crude oil inlet feed; a regenerated wash water pump stream, where the regenerated wash water pump stream pumps regenerated water into an output stream from the LPPT container to form an input LPDT feed stream; and current</p>

<p dir="rtl">fifteen Recycled Water from the LPDT Tank The recycled water stream from the LPDT Tank pumps the recycled water from the LPDT Tank to an output stream from the HPPT vessel to form an input feed stream</p>

.LPPT

In some embodiments, the system also includes a strip gas stream inlet in fluid contact with the LPDT reservoir, and the strip gas stream inlet serves to supply steam, in addition to or instead of stripping gas

<p dir="rtl">twenty Low concentration H2S, to LPDT buffer. In other embodiments, the system also includes a gas compressor unit, wherein the gas compressor station comprises a high pressure compressor that processes the high pressure exhaust gas from the HPPT container, a low pressure compressor that treats low pressure exhaust gas from the LPPT container, and an atmospheric compressor operating On the treatment of exhaust gas under atmospheric pressure from LPDT storage. In certain embodiments, the system includes a device</p>

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Oil Water Separation Receives an oil water output stream from the HPPT container, separates the oil from the water, and recycles the oil to the LPDT stockpile.

In other embodiments, the system also includes at least one mixing valve before the HPPT container, and at least one mixing valve before the first heat exchanger, whereby the mixing valves serve to mix

<p dir="rtl">5 Crude oil and water. In other embodiments as well, the system refines the crude oil in the crude oil input feed stream to produce a refined crude oil product that is safe for storage and shipping in accordance with the following specifications: (i) a salt concentration of not more than about 4.5 kilograms salt/159,000 liters; (2) basic sediment and water (BSW) content not more than 0.3% by volume (V%); (3) an H2S concentration below about 60 ppm; and (4) a limit</p>

<p dir="rtl">ten The maximum RVP pressure is about 0.05 MPa and the maximum effective vapor pressure (true TVP) vapor pressure is about 0.09 MPa, absolute at 54.4 °C.</p>

In certain embodiments, the system comprises a parallel gas separator and a second strip gas stream, and the parallel degassing device is positioned across the fluid between the second heat exchanger and the LPDT storage and is connected via the fluid to the LPDT stockpile input feed, where the parallel degassing device works to slither

<p dir="rtl">fifteen The exhaust gas is at atmospheric pressure to be treated in the gas compressor unit, where the second strip gas stream lowers the H2S content and feeds the input stream to the LPDT reservoir.</p>

In other embodiments, too, the system includes an auxiliary separator in fluid contact with the output stream of the LPDT reservoir, connecting the auxiliary fluid separator to a third strip gas stream, and the auxiliary separator enabling the third strip gas stream to further reduce the H2S content in the stream

<p dir="rtl">twenty The output is LPDT. In certain embodiments, the system includes a cold stabilization unit, where the cold stabilization unit is fluidly connected to a second strip gas stream, the second strip gas stream reduces the H2S content of the crude oil in the cold stabilization unit, and the cold stabilization unit operates To remove volatile hydrocarbons from crude oil to produce a complete non-volatile crude oil product suitable for storage and shipment. In some embodiments, the cold mount unit consists of 16 stages</p>

25 Actual.

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In other embodiments, the system includes a third heat exchanger that is fluidly connected to the crude oil inlet feed stream and the HPPT container, where the third heat exchanger provides heat to the crude inlet feed stream, and at least part of the heat is generated from the oil product stream last ore. In other embodiments, the system includes a parallel gas separator in position through the fluid between a valve

<p dir="rtl">5 At least one mixing before the HPPT container and the third heat exchanger and connecting it with them through the fluid. The parallel gas separation device separates the crude oil from the high pressure exhaust gas, where the gas compressor works to treat the high pressure exhaust gas from the parallel gas separation device. In certain embodiments, the system includes a second parallel gas separator in-place through the fluid between the second heat exchanger and the LPDT reservoir and connected to them in the fluid, the gas separator operates</p>

<p dir="rtl">ten The second parallel is to remove the exhaust gas under atmospheric pressure from the LPDT stockpile input feed stream for treatment in the gas compressor unit.</p>

In other embodiments, too, the system comprises a second gas stream that is fluid-connected to the LPDT stockpile input feed, an auxiliary separator fluid-coordinated to the LPDT stock output stream, and an additional separator fluid-coupled to a third strip gas stream, and the auxiliary separator serves to enable stream

<p dir="rtl">fifteen The third stripping gas will further reduce the H2S content in the LDPT stock output stream. In other embodiments, the operating pressure inside the HPPT container is greater than the operating pressure inside the LPPT container, and the operating pressure inside the LPPT container is greater than the operating pressure in the spool</p>

.LPDT

In some embodiments, the system dries, desaltifies, desalts and stabilizes the crude oil to produce 20 crude oil that is safe for storage and shipping without any drying or desalination units other than an HPPT container.

LPPT and LPDT buffer. In some embodiments, at least one input mixing device includes a sort separator.

In addition to this, an integrated system for a gas-oil separation plant is disclosed in this document. The system includes: a crude oil inlet feed stream, a crude oil inlet feed stream that transports oil

<p dir="rtl">25 low pressure acidic ore for processing in the system; and low . production holding container</p>

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LPPT (pressure production trap), in which the LPPT container is fluidly connected to the crude oil inlet feed, and where the LPPT container includes an inlet mixing device that thoroughly mixes the LPPT inlet feed stream, a set of insulated electrostatic electrodes, and a fence; LPDT (low pressure degassing tank), where the pair of

<p dir="rtl">5 LPDT stockpile via fluid in an LPPT container, wherein the LPDT stockpile includes an inlet mixing device well mixing the LPDT input feed stream, a set of insulated electrostatic electrodes, and a fence; and a stripping gas stream inlet is in fluid contact with the LPDT stockpile, and the degassing stream inlet pumps steam in addition to or instead of lower concentration H2S stripping gas into the LPDT stockpile; and a parallel gas separator, wherein the parallel gas separator is fixed in position via</p>

<p dir="rtl">ten The fluid is between the crude oil inlet feed stream and the LPPT container, and is placed across the fluid between the crude oil inlet feed stream and the LPPT container; and a first heat exchanger, where the first heat exchanger is placed through the fluid between the parallel gas separator and the LPPT container and connected through the fluid to both the parallel gas separator and the LPPT container, and where the first heat exchanger heats the LPPT input feed stream; And a second heat exchanger, where the second heat exchanger is fixed in place through the</p>

<p dir="rtl">fifteen the fluid between the LPPT container and the LPDT stockpile and compared via the fluid to both the LPPT container and the LPDT stockpile, where the second heat exchanger heats the LPDT stock input feed stream; Recycled Water Stream from the LPDT Vessel The recycled water stream from the LPDT Vessel supplies recycled water from the LPDT Vessel to the crude oil inlet feed stream to form an LPPT inlet feed stream, and a desalination unit placed across the fluid between the LPDT reservoir and the stabilizing module cold,</p>

<p dir="rtl">twenty The desalination unit removes brine from crude oil; and a third heat exchanger. The third heat exchanger is fixed in place through the fluid between the LPDT storage and the desalination unit. The third heat exchanger heats the crude oil output stream from the LPDT stockpile; and a regenerated wash water pump stream, where the regenerated wash water pump stream pumps the regenerated water to the LPDT stock output stream to form a feed stream entering the desalinator unit.</p>

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In some embodiments, the system includes a gas compressor, where the gas compressor includes a low-pressure compressor that treats the low-pressure exhaust gas from the parallel gas separator and LPPT container, an atmospheric compressor that treats the exhaust gas at atmospheric pressure from the LPDT stockpile and a gas compressor unit Cold install. In some embodiments, the system includes

<p dir="rtl">5 The oil-water separator receives an oil-water output stream from the LPPT container, separates the oil from the water, and recycles the oil to the LPDT stockpile. In other embodiments, the system includes at least one mixing valve before the first heat exchanger, at least one mixing valve before the second heat exchanger, and at least one mixing valve before the desalination unit, whereby the mixing valves serve to mix the crude oil and water.</p>

<p dir="rtl">ten Also in other embodiments, the system refines acidic crude oil in a crude oil inlet feed stream to produce a refined crude oil product that is safe for storage and shipping in compliance with the following specifications: (2) Basic sediment and water content (BSW, not more than 0.3% by volume V%); (3) an H2S concentration below about 60 ppm; and (4) a maximum RVP pressure</p>

<p dir="rtl">fifteen about 0.05 MPa and the maximum true vapor pressure (TVP) of about 0.09 MPa absolute at 54.4 °C. In certain embodiments, the system includes a second strip gas stream in fluid contact with the cold stabilization unit, the second strip gas stream reduces the H2S concentration in the crude oil in the cold stabilization unit, and the cold stabilization unit removes volatile hydrocarbons from the oil Crude to produce a non-crude oil product</p>

<p dir="rtl">twenty Fully volatile, suitable for storage and shipping.</p>

In some embodiments, the cold mount unit consists of 16 actual stages. In other embodiments, at least part of the heat is generated from a final crude oil product stream. In other embodiments, the operating pressure inside the LPPT tank is greater than the operating pressure in the LPDT tank. In certain embodiments, the system dehydrates, desalinates, and stabilizes the crude oil to produce crude oil that is safe for storage.

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And shipping without any desiccant or desalting units other than LPPT container, LPDT tank, desalination unit, and cold mount unit.

In addition to this, a combined method for separating gas from oil is disclosed in this document. The method comprises the following steps: separation under high pressure, high pressure exhaust gas and water.

<p dir="rtl">5 oil from crude oil, which supports the separation process by electrostatic fusion; heating the crude oil after it is separated from the oily water and high-pressure exhaust gas; Separation, under reduced pressure, of the low-pressure exhaust gas and water from the crude oil, whereby the separation process is supported by electrostatic fusing; Recycling the water after the separation, under low pressure, to be mixed with the crude oil before the separation step, under high pressure; mixing regenerated water with crude oil; Heating the crude oil after</p>

<p dir="rtl">ten separated from water and low pressure effluent gas; separating, at atmospheric pressure, exhaust gas at atmospheric pressure and water from crude oil; The separation process is supported by electrostatic docking, recycling of water after separation, under atmospheric pressure, to be mixed with crude oil before the separation step, under reduced pressure; And the production of a raw product after drying, desalination, stability and sweetening to be safe for storage and transportation.</p>

<p dir="rtl">fifteen In some embodiments, the method also includes the step of applying a stripping gas stream to reduce the H2S content of the crude oil, since the stripping gas stream consists of a gas with a lower H2S concentration than the crude oil. In other embodiments, the method comprises the step of collecting the high pressure effluent gas, the low pressure effluent gas, and the atmospheric effluent gas for treatment. In other embodiments also, the method comprises the oil-water separation step in the oil-water output stream, and the oil recycling from the output water-stream</p>

<p dir="rtl">twenty oil to be subjected to further processing. In some embodiments, the method refines the crude oil in a crude oil input feed stream to produce a crude oil product that is safe for storage and shipping in accordance with the following specifications: (1) a salt concentration of not more than about 4.5 kilograms of salt/159,000 liters; (2) The content of basic sediment and water (BSW) is not more than 0.3% by volume (V%); (3) an H2S concentration below about 60 ppm; and (4) a maximum</p>

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The RVP pressure is about 0.05 MPa and the maximum effective vapor pressure (true vapor TVP pressure) is about 0.09 MPa absolute at 54.4 °C.

In other embodiments, the method includes the step of applying a second stripping gas stream to reduce the H2S content of the crude oil, since the stripping gas stream consists of gas with a lower H2S concentration than the crude oil. in models

<p dir="rtl">5 Other, the method includes crude oil desalination and crude oil stabilization steps to reduce the H2S content in the crude oil; Removal of volatile hydrocarbons from crude oil to produce a complete non-volatile crude oil product that is suitable for storage and shipment.</p>

In other embodiments also, the method comprises a step of heating the crude oil before a separation step, under high pressure, high pressure vent gas and oily water from the crude oil, whereby the separation is supported

<p dir="rtl">ten by electrostatic fusion. In other embodiments also, a separation step is performed, under high pressure, of the high-pressure effluent gas and oily water from the crude oil, whereby the separation is supported by electrostatic fusion, to remove about 98% of the emulsified water contained in the crude oil. In certain embodiments of the method, the method is performed to dry, desalinate, desalinate and stabilize the crude oil to produce crude oil that is safe for storage and shipment without any drying or desalination units other than a high production holding container</p>

<p dir="rtl">fifteen Pressure, low pressure production holding container, and low pressure gas removal storage.</p>

In addition to this, a combined method for separating gas from oil is revealed. The method includes the following steps: heating the crude oil, as the crude oil includes an acidic low pressure crude oil; Separation, under reduced pressure, of low-pressure vent gas and water from the crude oil, whereby the separation is supported by electrostatic docking to produce a partially dry crude oil; Crude oil heating

<p dir="rtl">twenty Partially dry after being separated from water and low pressure effluent gas; separating, at atmospheric pressure, vented gas at atmospheric pressure and water from partially dry crude oil to produce more partially dry crude oil, where separation is supported by electrostatic docking; Recycle the water after it is separated, under atmospheric pressure, to be mixed with the crude oil separation step, under low pressure; heating other batches of partially dry crude oil; Mixing other batches of partially dry crude oil Wash water</p>

<p dir="rtl">25 renovated; Partial desalination of other batches of dry crude oil to produce recycled brine</p>

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desalination, dry crude oil; Recycling of recycled brine for mixing with partially dry crude oil prior to the separation step, under atmospheric pressure; Stabilization of dry crude oil after desalination to remove volatile hydrocarbons from crude oil; desalination of dry crude oil to reduce H2S content in dry crude oil after desalination; And the production of a raw product after drying, desalination, 5 stability and sweetening to be safe for storage and transportation.

In some embodiments, the desalination step of the crude oil includes the application of a stripping gas stream to reduce the H2S content of the crude oil, since the stripping gas stream consists of a gas with a lower H2S concentration than the crude oil. Also in other embodiments, the method also includes a step of collecting a low-pressure vent gas and an atmospheric vent gas for treatment. In other embodiments also, the method 10 comprises the oil-water separation step in the oil-water output stream, and recycling the oil from the oil-water output stream for further treatment. In some embodiments, the method is conducted to refine low-pressure acidic crude oil to produce a refined crude oil product that is safe for storage and shipping in compliance with the following specifications: (1) a salt concentration of not more than about 4.5 kilograms of salt/159,000 liters; basic sediment and water (BSW) not more than 15 0.3% by volume (V%); (3) an H2S concentration below about 60 ppm; and (4) a limit

The maximum RVP pressure is about 0.05 MPa and the maximum effective vapor pressure (true TVP) vapor pressure is about 0.09 MPa absolute at 54.4 °C.

In some embodiments, the method includes the step of applying a second stripping gas stream to reduce the H2S content of the crude oil, since the second stripping gas stream consists of a gas with a lower H2S concentration than the crude oil. In other 20 embodiments, a separation step is carried out, under reduced pressure, the low-pressure effluent gas and water from

Crude oil, where separation is supported by electrostatic docking, to remove about 98% of the emulsified water present in the crude oil. In some embodiments of the method, the method is performed to dry, desalt, desalinate and stabilize the crude oil to produce crude oil that is safe for storage and shipping without any drying or desalting units other than a high pressure production holding container, a low pressure production holding container, and a 25 gas sewage storage Low pressure, cold mount unit. In some embodiments, at least a portion is generated

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It is the heat that is devoted to heating crude oil from a crude oil product after drying it, removing its salinity, stabilizing it and desalinating it.

Brief explanation of the graphics

These features, aspects, and advantages that are unique to the disclosure and others will be revealed in the light of the following explanations,

<p dir="rtl">5 Protection elements and attached figures. However, it should be noted that the figures only display several models for detection, so it cannot be considered that the scope of detection is limited to them only, as other models can be accepted with the same efficiency.</p>

Figure 1 is a flowchart illustrating three phases in a conventional GOSP system and process for processing crude oil from production wells in a hydrocarbon-bearing ground formation.

<p dir="rtl">ten Figure 2 is a schematic diagram of a conventional GOSP system and process.</p>

Figure 3 is a schematic diagram of a combined GOSP process of the present disclosure that is used to process sweet crude oil.

Figure 4 is a schematic diagram of a combined GOSP process according to the present disclosure that is used to treat sour crude oil, comprising a cold stabilization process (in other words

<p dir="rtl">fifteen installation without boilers) using degassing gas with steam or a substitute for steam.</p>

Figure 5 is a schematic diagram of a combined GOSP process according to the present disclosure used to treat sour crude oil, comprising a cold stabilization process using a steam stripper and a desalting unit or an alternative.

Figure 6 is a schematic diagram of the combined operation of a GOSP based on the current disclosure

<p dir="rtl">twenty Using m additional disconnecting relays and parallel disconnecting devices.</p>

Detailed description:

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While the disclosed invention is described by description in the light of several models, it is understood that it is not intended to limit the disclosed invention to those models only. In contrast, it is intended to include all alternatives, modifications, and equivalents as they fall within the substance and scope of the disclosure defined in the attached claims.

<p dir="rtl">5 Referring to Figure 1, a flowchart illustrating three phases in the GOSP system and process for treating crude oil from production wells into a land formation carrying hydrocarbons is presented. In a first stage, gas, crude oil, and free water are separated. In a second stage, the crude oil is dried and desalted to separate emulsified water and salt to meet certain specifications for base sludge and water (RSW). In a third stage, the crude oil is stabilized and sweetened to meet the specifications of hydrogen sulfide, hydrogen sulfide</p>

<p dir="rtl">ten H2S (Hydrogen sulfide) and vapor pressure according to the RVP Reid method. In general, an acidic crude oil is referred to as any crude oil with a total sulfur level above about 0.5% by weight. In upstream operations, as described herein, the term sour crude refers to any crude oil with an H2S content higher than about 60ppm by weight, and sweet crude oil refers to crude oil with an H2S content less than about 60ppm by weight.</p>

<p dir="rtl">fifteen Figure 2 is a schematic diagram showing a traditional GOSP system and process. In the conventional GOSP 200 system and process, a wet crude oil inlet stream 202 from an oil production well (not shown) enters a high pressure production holding container (204 HPPT) and goes through a three-stage primary separation process to remove gases and free ground formation water from the wet crude oil A pressure drop in the 204 HPPT container causes lighter hydrocarbon gases to be generated in the crude oil to separate it from the hydrocarbons.</p>

<p dir="rtl">twenty heavier liquid. Operating conditions in the HPPT container include a temperature in the range of about 18°C ​​to about 54.4°C, and a pressure of about 1.03 MPa. The GOSP 200 system and process also includes an emulsifier injection port 206, a metal core valve 208, and an inlet diverter 210.</p>

Wet crude oil, as used in the written description, generally refers to crude oil with a ratio of

<p dir="rtl">25 Water is greater than about 0.3% by volume, while dry crude oil has a water content of less than about</p>

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0.3% by volume. The term refers to lighter hydrocarbons as used throughout the written description

Generic to 4-C1 components, eg, methane, ethane, propane, butane, iso-butane, and trace amounts of C5+ compounds. The phrase heavier hydrocarbons as used in the written description generally refers to C5+ hydrocarbons or containing more than five carbon atoms and more, eg 5, pentane, isopentane, hexane, and heptane. Heavier hydrocarbons may contain trace amounts

of lighter hydrocarbons.

An oil water remove stream 212 from a 204 HPPT container is drained to collect it in a water/oil separation vessel 214. The crude oil output stream from a 216 HPPT container also contains a certain amount of water and gas, and continues to the second stage in the conventional GOSP 200 process and system, which is holding container

<p dir="rtl">ten Low pressure production (218 LPPT. The high pressure gas output stream is then completed from a container</p>

220 HPPT is routed to compressor station 222, which includes a high pressure compressor 224 to process high pressure gas. The output stream of the high pressure gas from the 220 HPPT container ranges, in some embodiments, from about 1.03 MPa to about 3.1 MPa depending on the crude oil pumping pressure. It may include a high pressure gas output stream from the HPPT container

<p dir="rtl">fifteen 220 on lighter hydrocarbons, trace amounts of N2, CO2, H2S, C5 + hydrocarbons,</p>

water vapor; However, the relative quantities and types of compounds depend on the crude oil income feed-stream.

The 218 LPPT container removes the remainder of a certain discharge gas in the crude oil output stream from the 216 HPPT container. The 218 LPPT container also includes an inlet transformer 226. The 218 LPPT container is a horizontal two-stage separation vessel, which separates the remainder of the designated discharge gases from the wet crude oil. 20 A 218 LPPT container operates under less pressure than a 204 HPPT container. Includes outlets from container

218 LPPT a low-pressure drain gas stream from the LPPT 228 container, which continues to compressor station 222 and a low-pressure compressor 230, and an output stream of wet crude oil from the 232 LPPT container, which completes in a subsequent treatment. Operating conditions in an LPPT 218 °C include a temperature in the range of about 18 °C to about 54.4 °C.

<p dir="rtl">25 And pressure at a rate of about 0.34 MPa per scale.</p>

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The low pressure exhaust gas stream from a 228 LPPT container ranges from 0.34 MPa to about 0.62 MPa. The low pressure vent gas stream from the 228 LPPT container may include lighter hydrocarbons, a small amount of

N2, CO2, H2S, C5 + hydrocarbons, and water vapour; However, the relative quantities and types of

<p dir="rtl">5 The vehicles depend on the crude oil income feed stream.</p>

The wet crude oil output stream from the LPPT 232 container continues its path to a first heat exchanger 234 where the heat can be recovered from the downstream of the LPPT product 236, then reheating any oil, water, and gas into the wet crude oil output stream from the container 232 LPPT. Wet crude heating allows for easier separation of water from crude oil with increased water retention and lower temperature

<p dir="rtl">ten Crude oil from a well or pipeline. Heating the crude oil helps to improve the oil/water separation process, and improve the efficiency of desalination and drying processes by lowering the viscosity of the emulsion and stabilizing the crude oil equilibrium. In other words, heating allows the water droplets to coalesce and settle into the liquid phase, encouraging degassing from the crude oil in order to stabilize the crude oil.</p>

The heated crude oil output stream 238 from the heat exchanger 234 continues its path to a storage tank.

<p dir="rtl">fifteen Low pressure gas for a three-stage separation unit (LPDT 240), with which the pressure drops to</p>

About 0.02 MPa, so that any remaining heavy gas components can be vanished by boiling. Heavy gas components in the LPDT 240 case may include propane, iso-propane, CO2, H2S and C5+ hydrocarbons; However, the relative quantities and types of compounds depend on the crude oil income feed-stream. Operating conditions for a 240 LPDT stock include a temperature in the range of about 18

<p dir="rtl">twenty degrees Celsius to about 54.4 degrees Celsius and a pressure ranging from about 0.02 MPa to about 0.03 MPa on the scale. A gas stream at atmospheric pressure continues from container 240 LPDT to compressor station 222 and compressor 244. Oil water continues through stream 241 to oil/water separation vessel 214.</p>

The crude oil output stream is pumped from the 246 LPDT reservoir through the 248 . crude oil charge pumps

<p dir="rtl">25 It continues its path to a stabilizing heat exchanger 250 to increase the temperature of the LPDT crude oil outlet stream</p>

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<p dir="rtl">246. The LPDT crude oil outlet stream then continues its path through a mixing valve 252, in which the crude oil outlet stream 246 LPDT is mixed with a recycled wash water stream 254 before moving to the dryer unit 256 for further water-oil separation. Heating the crude oil output stream from the LPDT 246 storage using a balancer heat exchanger 250 enhances the efficiency of the drying and desalination processes, eg 5 in the 256 dryer. The heat exchangers may be of a tube/casing type, in which moist crude oil passes through the inner tubes and the heating medium is placed inside an outer shell that encloses the tubes.</p>

The recycled wash water stream 254 is mixed with the crude oil output stream from LPDT 246 in mixing valve 252 as soon as the crude oil output stream from the LPDT 246 storage tank is heated by a stabilizing heat exchanger 10 250. Recycled wash water stream 254 is generated from the desalting unit The first 258 before entering the unit

Drying 256. The drying unit 256 is a horizontal vessel in which a first stage of drying of wet crude oil is carried out. The washing and electrostatic docking process takes place in the dryer unit 256. The wet crude oil input 260 to the dryer unit 256 contains some of the free brine, and some of the brine in the form of an emulsion. The emulsion is separated into layers of oil and water 15 by electrostatic docking in the 256 drying unit.

Electrostatic fusing uses an electric current that causes water droplets in an emulsion to collide, coalesce into larger (heavier) droplets, and settle out of the suspended phase, such as crude oil. This process partially dries out the wet crude oil. Oily water continues through an output stream Oily water 262 to an oil/water separation vessel 214. The output stream of a dehydrator unit 264, which is still 20 containing some brine in the form of an emulsion, is supplemented to a first-stage desalination unit.

258 Via mixing valve 266. Operating conditions of the drying unit include 256°C in the range from about 54.4°C to about 71°C and a pressure of about 0.17 MPa above the crude oil vapor pressure. In the mixing valve 266, the dryer output stream 264 is mixed with the recycled water stream 268 from a second stage desiccant unit 270.

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A partially dried crude oil inlet stream 272 enters a first-stage desalter unit 258 after a desiccant unit 256. As noted, at a mixing valve 266, the dehydrator output stream 264 is mixed with a recycled water stream 268 from a second-stage desiccant unit 270. Water flowing from the first stage desalination unit 258 continues its path to the desiccant unit 256 through a recycled wash water stream 5 recycle 254. Operating conditions for the first stage desalination unit 258 include a temperature range

It ranges from about 54.4°C to about 71°C and has a pressure of about 0.17 MPa above the raw vapor pressure.

The second desalination unit 270 is the last stage of wet crude oil treated with a conventional GOSP plant. Completed partially dried crude oil output stream from first stage desalination unit 274

<p dir="rtl">ten Its path to the second stage desalination unit 270 from the first stage desalination unit 258. A regenerated wash water stream 276 (lower in salt concentration relative to the salt concentration of the emulsified water in the crude oil) is injected into the port of a second stage desalination unit mixing valve 278 To form an input stream of a second stage desalting unit 280 upon association with an output stream of partially dried crude oil from a first stage desalination unit 274. Rinse with low salinity wash water</p>

<p dir="rtl">fifteen Significantly all residual salt is from crude oil. Regenerated wash water is used in the desalination process to ensure that the maximum amount of salt is rinsed out from the wet crude oil. Electrostatic docking removes the residual water emulsion of wet crude oil from the second stage desalination unit 270 in the same way as the dryer 256 and the first stage desiccant unit 258. The water flowing from the second stage desalination unit 270 completes its path to the stage desalination unit</p>

twenty The first 258 via recycled water stream 268.

The salinity of the wash water may range from about 100 ppm to about 12,000 ppm. The salinity of the water in the land formation produced with the crude oil may rise to about 270,000 parts per million of salt.

The output stream of the second stage desalination unit 282 comprises of dry, desalinated crude oil

25 It passes to the decompression valve 284 and then to the crude oil stabilizer 286. Operating conditions include

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The second stage desalination unit has 270 heat range from about 54.4°C to about 71°C and a pressure of about 0.17 MPa above the raw vapor pressure.

Once the crude oil has been degassed, dried, and partially desalinated after the second stage desalination unit 5 270, there are two further steps that are applied before the crude oil is suitable

for storage, export and refining; They are sweetener and fixation. The desalination process involves the removal of dissolved H2S gas from crude oil to meet specifications in the range of about 10-60 ppm of H2S. Desalination is performed to reduce pipeline corrosion and avoid the health and safety risks associated with H2S. Steam may be used to degas H2S from crude oil in addition to or in place of any suitable degassing gas

<p dir="rtl">ten Others have a low H2S concentration relative to crude oil. Suitable stripping gas streams include low H2S natural gas such as methane, ethane, steam, and N2 nitrogen).</p>

The process of balancing the machines is done by heating unstable crude oil that contains dissolved gases and H2S, and splitting it into two components: gas from the upper stream and crude oil from the heavy products stream. can

<p dir="rtl">fifteen Crude oil stabilization stabilization If the crude oil is heated in several stages of separation cylinders operating under increased temperatures and low pressures, for example, in a crude oil stabilization unit 286. The oil stabilization unit performs two functions at the same time, including desalination Sour crude oil by removing hydrogen sulfide and reducing water vapor, then securing crude for shipping in pipelines.</p>

The stabilization process involves the removal of light products, mostly C1-C4 hydrocarbons, from petroleum.

<p dir="rtl">twenty Crude, to reduce vapor pressure to produce a stable, less volatile product that can be stored in storage at atmospheric pressure. The process of balancing the machines also aims to reduce the vapor pressure of crude oil to about 0.9 MPa at least below the atmospheric pressure, so that any steam rises suddenly under atmospheric pressure conditions, which secures the transportation and shipping processes. The operating temperature of the crude oil stabilization unit 286 ranges from about 71 ° C to about 93 ° C and the pressure varies</p>

25 From about 0.02 to about 0.03 on the scale.

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The oil leaving the second stage desalination unit 270 completes its path to the top of the crude oil stabilization unit 286 and is distributed to an overhead tray. The Crude Oil Stabilizer 286 includes a number of trays (for example, up to about sixteen), so the crude oil flows down through each tray until it reaches the intake tray. A boiler is heated with currents carrying 288 dry crude oil from

<p dir="rtl">5 Intake tray and back to the Crude Stabilizer 286. Light components in the crude oil evaporate and rise through the Stabilizer Trays. Hydrogen sulfide and light hydrocarbons are removed as a gas stream at 290 atm, which resumes to the gas compressor 222 and the compressor 244.</p>

A crude oil stabilization unit product downstream 236 continues its path to a crude charging pump 292, and a dry crude product suitable for storage and shipment 10 is supplied via a dry crude product stream 294.

Crude Stabilizer 286 to meet specifications for RVP pressure and H2S content. After the stabilization and desalination process, the crude oil must meet all specifications for shipment. These specifications include the following: (1) a salt concentration of not more than about 10 PTB; (2) a BSW content of not more than 0.3% by volume V%; (3) an H2S content of a concentration less than about 60 ppm either 15 in a stabilization tower. balancing oil (or degassing vessels in the case of sweet crude (no sulfur); and (4) limit

The maximum pressure for RVP is about 0.05 MPa and the maximum pressure for TVP is about 0.09 MPa at 54.4 °C.

Oil/Water Separation Vessel 214 collects water from streams from the 204 HPPT container, storage

240 LPDT, 256 dehydrator unit, separates oil from collected water. Waste water is discharged

<p dir="rtl">twenty By waste water stream 29 to waste water wells and transport the extracted oil to LPDT storage</p>

240 by recycle stream 298.

Referring now to Figure 3, a schematic diagram of an integrated GOSP plant as per the present disclosure is shown which is used to process sweet crude oil. Certain benefits of the combined GOSP 300 system include eliminating a crude oil stabilizer, eg, Crude Stabilizer 286, eliminating boiler 25 of the Crude Stabilizers, such as a load current boiler 288, and eliminating certain charge pumps, eg.

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Example, crude oil charge pumps 248, first stage desalination unit removal, eg first stage desalination unit 258, second stage desalination unit canceling, eg second stage desalination unit 270, oil drying unit scrap Raw, eg drying unit 256. Other benefits include compact GOSP systems and methods5 that are compact, efficient, easy to move, portable, and for use in small-scale and offshore applications.

Existing detection models reduce the need for units in land-based coastal applications, while also lowering operating costs.

In the combined GOSP 300 system, a sweet crude oil feedstock 302 feeds a mixed unstable wet sweet crude oil with brine from production wells in a land formation carrying hydrocarbons to a container

<p dir="rtl">ten 304 HPPT. The sweet crude oil feed inlet 302 includes an injection port 306 and a mixing valve 308,</p>

Through which flows sweet crude oil and a demulsifier agent. The sweet crude oil feed inlet 302 is mixed with recycled water stream 342 from the 334 LPPT container before entering the 304 HPPT container. Emulsifiers stimulate the desalination process and enable the treatment of "tight" emulsions. Also referred to as emulsifiers, demulsifiers for materials

<p dir="rtl">fifteen Chemical that is used to separate emulsions, for example, water in oil. For example, one of the de-emulsifying agents is PHASETREAT® by Clariant, Muttens, Swiss R.</p>

The 304 HPPT enclosure includes a high-efficiency input mixer 310, 312 electrostatic electrodes, and 314 fencing. Suitable insulated electrostatic electrodes 312 are commercially available.

<p dir="rtl">twenty It improves the ability to operate the compact GOSP 300 system at 100% liquid or 100% gas, and eliminates the need to operate units, eg desalination units, at 0.17 MPa above the crude vapor pressure, which is required in conventional desalination units. The electrostatic electrodes include the vessel internal electrostatic VIEC's (coalescers) of Wartsila Corporation, Helsinki, Finland. Complete</p>

<p dir="rtl">25 High-pressure gas from a 304 HPPT container is routed to a 316 compressor station involving a piston</p>

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High Pressure 318. The oily water from the 304 HPPT completes its path through an oil water stream 320 to the oil/water separator 322. The 314 fence helps physically separate the oil from the water inside the 304 HPPT container, and helps maintain an adequate oil level within the vessel.

The pressure drop in the 304 HPPT container causes lighter hydrocarbon gases to be generated in the crude oil

<p dir="rtl">5 To be separated from the heavier liquid hydrocarbons. Light hydrocarbons, eg methane and ethane, can be separated in a 304 HPPT container. The isolated electrostatic electrodes 312 synchronously dried the crude and largely removed the emulsified water up to about 98%.</p>

The 324 HPPT container crude oil output stream includes partially dried crude oil and continues its path to a 326 mixing valve where the partially dried crude oil is mixed into a containerized crude oil output stream

<p dir="rtl">ten 324 HPPT with recycled water stream 328. Mixed oil and water stream 330 complete its path</p>

To the first heat exchanger 332 for heating. The first heat exchanger 332 precedes the 334 HPPT container. Note that the first heat exchanger 332 before the 334 LPPT container is different from that of the assembly in Figure 2, where the first heat exchanger 234 precedes the 240 LPDT stockpile and not the 21 LPPT container. Heating the wet raw material allows for easier gas separation and enhances the efficiency of the drying processes

<p dir="rtl">fifteen And desalination.</p>

The 334 LPPT container, a horizontal three-phase separator, includes a 336 high-efficiency input mixer, 338 insulated electrostatic electrodes to separate the emulsified water, and a fence 340 to aid physical oil-water separation. High-efficiency input mixers, such as the 336 high-efficiency input mixer, help to mix ingredients with crude oil, such as wash water, to neutralize

<p dir="rtl">twenty And well. Recycling water stream 342 recovers water from the bottom of a 334 LPPT container to desalinate the feed input</p>

Crude oil 302 for mixing in a mixing valve 308. The low pressure gas is transmitted through a low pressure gas stream 344 to the gas compressor unit 316 and the low pressure compressor 346. The operating pressure of the 334 LPPT container is lower than the 304 HPPT container to allow the gases to be removed. The pressure of the LPPT container is usually within 1/3 of the pressure of the 304 HPPT container to reach optimum

<p dir="rtl">25 Who retrieved the question. The output from the 334 LPPT container is exhaust gas that continues to</p>

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Compressor unit 316 via low pressure gas stream 344, ground formation water recirculated to the 304 HPPT container upstream from the 308 mixing valve, and partially dried crude oil continuing to the 358 LPDT reservoir for desalination and stabilization.

The crude oil output stream from the 348 LPPT container continues to the 350 mixing valve to be mixed

<p dir="rtl">5 With regenerated wash water from wash water stream 352. The LPPT 348 container crude oil output stream, which consists of dry LPPT 334 container crude oil, contains some components or light impurities that need to be reduced in other proportions. These impurities include CH4, CO2, N2, H2S, C3H6, C2H4, water, and any other suspended solids or volatile gases. The dry ore is mixed with the regenerated wash water in a mixing valve, such as the 350 mixing valve, or other water dispersal mixers.</p>

<p dir="rtl">ten Fine pure drops to reduce the concentration of salt content or any other impurities. Rinse wash water low</p>

Salinity The residual salt of crude oil. Regenerated wash water is used in the desalination process to ensure that the maximum amount of salt is rinsed out from the wet crude oil. Injection of low salinity water before the stabilizing heat exchanger 356 minimizes sediment formation.

The mixed oil and water stream 354 enters the stabilizing heat exchanger 356 to be heated before entering the storage

<p dir="rtl">fifteen 358 LPDT. The 358 LPDT buffer includes a 360-degree high-efficiency input mixer, electrodes</p>

Electrostatic isolated 362 to separate the emulsified water, and a fencing 364. It is noted that the stabilizing heat exchanger 356 precedes the storage unit 358 LPDT, which differs from that in the model shown in Figure 2, where the stabilizing heat exchanger 250 precedes the dryer unit 256. Mixing 326 First heat exchanger 332 and container 334 LPPT in Figure 3, preceded by

<p dir="rtl">twenty Mixing Valve 350 The stabilizing heat exchanger 356 and 358 LPDT stockpile in Figure 3. This is significantly different from the location of the mixing valves shown in Figure 2, as there is no mixing valve in Figure 2 that precedes either the 218 LPPT container or the 240 LPDT stockpile. Electrostatic docking in the 358 LPDT tank removes largely all water-residual emulsion from the wet crude oil in the same manner on the sinks of the second-stage desalination units at the GOSP plant, but</p>

<p dir="rtl">25 For example, the second stage desalination unit 270.</p>

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The LPDT stockpile 358 includes an optional sweet degassing stream 366, eg steam in addition to or in place of one or more gases with a lower H2S content relative to the crude oil, to remove or remove H2S from the crude oil, depending on whether the crude oil is sweet or acidic; The 358 LPDT tank operates under less pressure than the 334 LPPT tank, and the pressure to remove is greatly compressed.

<p dir="rtl">5 All gaseous impurities needed for the crude oil to match the conditions for RVP pressure and H2S content. The operating pressure can range from as high as 0.07 MPa to vacuum conditions. An atmospheric gas stream 368 continues its path from the 358 LPDT storage to a compressor at 370 atm at the 316 compressor station. Compressed gas from the integrated GOSP system 300 exits via the gas output stream 374. Water is recycled from the 358 LPDT stockpile via a stream</p>

<p dir="rtl">ten 328 recycled water into a 334 LPPT container. Water from the 358 LDPT tank is recycled through the 328 recycled water stream to the 334 LPPT container. The pump pumps 372 stable, unsalted dry crude oil from the 358 LPDT stockpile through the 376 stable, unsalted dry crude oil product line. Water from the oil/water separator 322 exits through a water output stream 378.</p>

In some embodiments, exhaust gas under atmospheric pressure is released from the LPDT storage at a rate of 15 between about 0.1 MPa and about 0.17 MPa, and low exhaust gas is released

The pressure from the LPPT container is about 0.45 MPa, and the high-pressure exhaust gas comes out from the HPPT unit at the rate of about 1.14 MPa and greater.

The composition of high pressure vent gases, low pressure vent gases, and effluent gases under atmospheric pressure vary according to the temperature and pressure in the HPPT, LPPT container.

<p dir="rtl">twenty and store LPDT. Moreover, the composition of high-pressure exhaust gases, gases</p>

The outgoing is of low pressure, and the outgoing gases are under atmospheric pressure on the crude oil's inlet temperature, pressure and composition. Low pressure exhaust gas contains higher molecular weight compounds than high pressure exhaust gas, and low pressure exhaust gas contains higher molecular weight compounds than low pressure exhaust gas. In some embodiments, a high-pressure compressor receives

<p dir="rtl">25 High pressure exhaust gas at a rate of about 1.03 MPa and the exhaust gas is compressed</p>

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High pressure to about 3.1 MPa gauge; A low pressure compressor receives a low pressure exhaust gas of 0.34 MPa and compresses the low pressure exhaust gas to about 1.1 MPa; A compressor under atmospheric pressure receives the outgoing gas under atmospheric pressure at a rate of about 0.05 MPa per scale and compresses the gas

<p dir="rtl">5 The discharge is under atmospheric pressure to about 0.41 MPa on the scale.</p>

After the drying, desalination, stabilization and sweetening (as necessary) process has been completed the crude oil should comply with all specifications required for shipping, transportation, and storage. These specifications include: (1) a salt concentration of not more than about 10; (2) A BSW content of not more than 0.3% by volume V%; (3) an H2S content at a concentration of less than about 60 ppm either in an oil balance stabilization tower (or

<p dir="rtl">ten Degassing vessels for sweet crude (no sulfur); and (4) maximum RVP pressure of about 0.05 MPa and maximum pressure of TVP of about 0.09 MPa at 54.4 °C.</p>

In some models to operate the system shown in Figure 3, the results shown in Table 1 are reached after the crude oil exits the 358 LPDT reservoir.

<p dir="rtl">fifteen Table 1. Characteristics of crude oil processed via the current invention model versus a conventional GOSP system.</p><table border="1"><tbody><tr><td><p dir="rtl">The model shown in Figure 3</p></td><td><p>GOSP System</p></td><td></td></tr><tr><td><p dir="rtl">Less than 0.07 MPa</p></td><td><p dir="rtl">Greater than about 0.07 MPa</p></td><td><p dir="rtl">salt content</p></td></tr><tr><td><p dir="rtl">Less than 0.3% by volume</p></td><td><p dir="rtl">About 1 to about 65% by volume</p></td><td><p>BS&amp;W</p></td></tr><tr><td><p dir="rtl">Less than 0.05 MPa</p></td><td><p dir="rtl">about 0.11 MPa</p></td><td><p>RVP</p></td></tr></tbody></table>

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<tr><td><p dir="rtl">Less than 60ppm (w/w)</p></td><td><p dir="rtl">Greater than about 60 ppm (w/w)</p></td><td><p dir="rtl">H2S . concentration</p></td></tr>

In some embodiments to operate the system shown in Figure 3, the operating conditions shown in the table are used

2 to process crude oil.

Table 2. Operating conditions in an embodiment of the present invention versus a conventional GOSP system.

<tr><td colspan="2"><p dir="rtl">The model shown in Figure 3</p></td><td colspan="2"><p dir="rtl">Conventional GOSP System</p></td><td></td></tr><tr><td><p dir="rtl">pressure, mega</p><p dir="rtl">Pascal</p><p dir="rtl">by scale</p></td><td><p dir="rtl">temperature,</p><p dir="rtl">Celsius</p></td><td><p dir="rtl">pressure mega</p><p dir="rtl">Pascal</p></td><td><p dir="rtl">temperature</p><p dir="rtl">percentage</p></td><td></td></tr><tr><td><p>1.14</p></td><td><p>35</p></td><td><p>1.14</p></td><td><p>35</p></td><td><p>HPPT input</p></td></tr><tr><td><p>1.4</p></td><td><p>102</p></td><td><p>1.14</p></td><td><p>35</p></td><td><p>HPPT output</p></td></tr><tr><td><p>0.97</p></td><td><p>135</p></td><td><p dir="rtl">There is no</p></td><td><p dir="rtl">There is no</p></td><td><p dir="rtl">The first heat exchanger came out</p></td></tr><tr><td><p>0.41</p></td><td><p>133</p></td><td><p>0.41</p></td><td><p>35</p></td><td><p>LPPT output</p></td></tr><tr><td><p>0.21</p></td><td><p>170</p></td><td><p>0.21</p></td><td><p>135</p></td><td><p dir="rtl">The second heat exchanger came out</p></td></tr><tr><td><p>0.12</p></td><td><p>158</p></td><td><p>0.12</p></td><td><p>128</p></td><td><p dir="rtl">capacitor charge</p><p>LPDT</p></td></tr>

5 The 322 oil/water separator collects oily water from a 304 HPPT container, 334 LPPT container,

358 LPDT was stored through an oil water stream 320, and the waste water was discharged to a waste water well and transported

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The oil is extracted to the 358 LPDT stockpile via a recycle line 380. In some embodiments, the 310, 336, and 360 input mixers include screen separators. Input mixing devices and separators improve the efficiency of gas-liquid separation in vessels such as LPPT, HPPT, and LPDT storage, and then the volume of vessels can be reduced, including LPPT, HPPT, and LPDT storage in

<p dir="rtl">5 Models of the present invention.</p>

In some embodiments shown in Figure 3, the systems and methods can be modified, as needed, to treat sweet or sour crude. For example, after the stabilizing heat exchanger 356, an optional parallel gas separator 382 and an optional auxiliary strip gas stream 384 can be operated depending on the H2S content of the crude oil and the final specifications required. The exhaust gas may come out under atmospheric pressure from

<p dir="rtl">ten Optional Parallel Gas Separator 382 Through a gas stream at 368 atm, the partially desalinated crude oil passes to the 358 LPDT stockpile after mixing with an optional additional strip gas stream 384. In the alternative, additional separation relays may come in addition to or instead of for one or more additional stripping currents after the 358 LPDT stockpile between the 358 LPDT and the 372 pump, eg an optional separator 386 and an optional strip gas stream 388.</p>

<p dir="rtl">fifteen Referring now to Figure 4, a schematic diagram of an integrated GOSP system according to the present disclosure is used to treat sour crude oil, including a cold stabilization process using stripping gas with steam or a substitute for steam. Likewise, the marked ingredients represent the ingredients as previously described in the written description.</p>

To process sour crude oil in the present disclosure models, a 20 402 cold stabilization unit (without boiler stabilization unit) can be used on about 16 actual stages to reach an H2S content of about

<p dir="rtl">ten ppm. A dry, highly unsalted crude oil input stream 404 is completed on a cold stabilization unit 402 to be sweetened and stabilized as necessary using strip gas stream 406. Strip gas stream 406 may comprise any suitable gas of low H2S concentration, in addition to steam or a substitute for steam. Suitable stripping gases include steam, methane, ethane, nitrogen, and gaseous gas.</p>

<p dir="rtl">25 Others are suitable with low H2S content relative to crude oil.</p>

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H2S and other volatile components (low molecular weight hydrocarbons) are exited from the cold stabilization unit 402 through a gas stream 408 to the gas compression station 316 and a compressor at 370 atmospheric pressure. After drying, stabilizing, and sweetening the crude oil is removed from the cold stabilization unit 402 via output stream 410 and pumped by a crude charge pump 412 to transfer stream 414.

<p dir="rtl">5 It is noted that the model shown in Figure 4 does not contain any drying devices or desalination units, which are found in the model shown in Figure 2. The combined systems and methods work according to the current disclosure in the absence of a separate separator and desalination units for the production of dry crude , localized and installed, in accordance with the shipping and transport specifications as listed in this document.</p>

Figure 5 is a schematic diagram showing an integrated GOSP system according to the current disclosure that is used

<p dir="rtl">ten For the treatment of acidic crude, it includes cold stabilization using a stripping gas with steam and a desalting unit or instead of them. In the combined GOSP 500 system, a low pressure sour crude oil feed stream 502 is completed through a parallel separator 504, mixing valve 506, and a first heat exchanger 508 before entering the 510 LPPT container. The demulsifier injection port 512 is in fluid contact with the low pressure crude oil inlet feed stream 502, and the 510 LPPT container includes</p>

<p dir="rtl">fifteen Also on a Farsi separator 514, insulated electrostatic electrodes 516, and fencing 518.</p>

Low-pressure gas stream 520 from parallel gas separator 504 and LPPT container 510 is completed to a compressor 522 and low-pressure compressor 524. After a low-pressure piston 524, the gas passes through a high-pressure piston 526 and outward through a gas output stream 528 from the compressor 522. 20. Emulsifying agents may be added, as needed at other sites, 20 instead of or in addition to the entry, in the embodiments shown in the present disclosure.

In mixing valve 506, low pressure crude oil inlet feed stream 502 is mixed with recycled water stream 530. In first heat exchanger 508, the mixed crude oil and recycled water are heated through a crude stream after drying, desalinating, stabilizing and desalting 532 FRS 514 and 510 LPPT separator. After the 510 LPPT container, the partially dried crude oil stream 534 completes its path through

<p dir="rtl">25 Mixing valve 536, second heat exchanger 538 and to storage 540 LPDT. In the mixing valve 536,</p>

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The partially dried crude oil stream 534 is mixed with the recycled water stream 560. In a second heat exchanger 538, the mixed recycle water and partially dried crude oil are heated.

The 540 LPDT stockpile comprises a Farsi separator 542, electrostatic electrodes 544, fencing 546, and strip gas stream 548, which may comprise any stripping gas with a low H2S concentration relative to the crude oil 5, in addition to or in place of steam. 530 recycled water stream exits storage bottom

540 LPDT, while a stream 550 atm exits near the top of storage 540 LPDT and continues its path to a piston 552 at gas compressor station 522 before exiting by the 528 gas output stream.

A partially dehydrated, degassed crude oil stream 554 is completed from the LPDT storage 540 to an oil charge 10 pump 556 and then to a third heat exchanger 558. After a third heat exchanger 558, regenerated water is injected through a regenerated water inlet 562 at a mixing valve 564 prior to entry. Second stage desalination unit 566. Water from the second stage desalination unit 566 is recirculated via a recycled water stream 560 to a mixing valve 536, and the crude oil stream after drying, desalination 568 is supplemented by its path to the cold stabilization unit 570. The strip gas stream 572 is in contact through the fluid with the unit

<p dir="rtl">fifteen Cold stabilization 570 to the gas compressor station 522, and a crude charging pump 574 pumping a crude stream after drying, desalting, stabilizing and desalting 532 to the first heat exchanger 508. Cold, dry crude oil for charging continues its course through stream 576. An oil water stream 578 from the 510 LPPT container and proceeds to the oil/water separator 580 before exiting by steam 582 to drain the treated water.</p>

<p dir="rtl">twenty It is noticeable that, in the embodiment shown in Figure 5, for a low pressure acid ore from production wells, a conventional desalination unit, a second stage desalination unit 566, a cold stabilization unit, and a cold stabilization unit 570, can be used on 16 actual stages to achieve The requirement for H2S concentration is around 1 ppm.</p>

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Referring now to Figure 6, a schematic diagram is shown showing an integrated GOSP system according to the present disclosure using additional tripping relays and parallel tripping devices. In a combined GOSP 600 system, a crude oil inlet feed stream 602, in fluid contact with a demulsifier agent injection port 604, passes through a mixing valve 606, a parallel separator 608, a first heat exchanger 610, and a separator

<p dir="rtl">5 Varsey 612 is on its way to the 614 HPPT container. The 614 HPPT container includes 616 electrostatic insulated electrodes and a 618 fencing to help separate the water from the oil. High-pressure exhaust gas travels from a parallel separator 608 and container 614 HPPT through a high-pressure exhaust gas stream 620 to a gas compressor station 622 and a high-pressure compressor 624 to finally exit the 600 GOSP system via a gas outlet 626.</p>

<p dir="rtl">ten Parallel gas separators include combined gas/liquid separators that apply screen separation techniques to generate high gravitational forces (“G-forces”) with low pressure drop to achieve high gas-liquid separation performance in a pipe coil landfill. Parallel separators can be considered as a phase Equilibrium separation, production of very high quality gas streams and separate liquids.</p>

The recycled water from the recycled water stream 628 is mixed with the crude oil inlet feed stream 602 15 in a mixing valve 606, and the mixture of crude oil and water in a first heat exchanger 610 is heated at least partially by a crude oil product stream after drying, desalination, Desalination and Stabilization 630. A cooled crude oil stream after drying, desalination, desalination and stabilization 632 flows away from the first heat exchanger 610 for charging. Oil water from the HPPT vessel continues its path through oil water stream 634 to an oil/water separator 636 for treatment, and process water is disposed of through stream 638. The oil that has been made can be recycled

<p dir="rtl">twenty Separate it from the oil/water separator 636 for further treatment (not shown).</p>

Partially dried crude oil stream 640 from container 614 HPPT is mixed with recycled water from recycled water stream 642 in a mixing valve 644 and heated in a second heat exchanger 646. The heated mixed crude oil and recycled water is then passed through a sorter 648 to 650 LPPT container for further processing. The LPPT treatment comprises 652 insulated electrostatic electrodes and a fence

<p dir="rtl">25 654. Water from the 650 LPPT container is recycled through the recycled water stream 628, and gas is completed</p>

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Low pressure drain from the 650 LPPT container via stream 656 to the 622 compressor station and the 658 low pressure piston.

Partially dry crude stream 660 out of the LPPT 650 container comprises partly dry crude oil and is mixed with regenerated water from regenerated water inlet stream 662 in a mixing valve 664 before being heated in an exchanger

<p dir="rtl">5 Third heat 667. A mixture of crude oil and regenerated water then passes to a parallel gas separator 668.</p>

The crude oil from the parallel gas separator 668 is combined with the stripper gas stream 670 that comprises steam in addition to or in place of any other suitable stripping gas at a lower H2S concentration relative to the crude oil, then the crude oil continues its path through the separator 674 to the 672 LPDT stockpile. . An exhaust gas under atmospheric pressure passes from a parallel gas separator 668 and a storage tank 672 LPDT

<p dir="rtl">ten Via a discharge gas stream 676 at atmospheric pressure to a compressor 678 to finally exit the integrated GOSP system 600 via a gas outlet stream 626. The LPDT buffer 672 comprises insulated electrostatic electrodes 680 and a fencing 682.</p>

After drying, desalination, desalination and partially stabilized, the crude oil is completed from LPDT stockpile 672 to an additional separation unit 684, which comprises an additional degassing stream 686 consisting of

<p dir="rtl">fifteen Steam in addition to or in place of any other suitable stripping gas in a low H2S concentration relative to crude oil. The crude oil charging pump 688 pumps the dried, desalinated, desalinated, and finally stabilized crude through a stabilizer crude oil product stream 630 to the first heat exchanger 610. A cooled crude oil product stream flows after drying, desalinating, desalting and stabilizing 632 at a distance from The first heat exchanger 610 for charging.</p>

<p dir="rtl">twenty Although the disclosure is described in relation to particular traits, it must be recognized that traits and embodiments of traits can be combined with other traits and embodiments of those traits.</p>

Although the disclosure is dealt with in more detail, it must be realized that many changes, alternatives and modifications can be introduced based on it without departing from the principle and scope of the disclosure. Accordingly, the current scope of disclosure should be determined in light of the following claims and their equivalent in a legitimate manner.

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Singular forms include the indefinite and the indefinite article indicating the plural, unless the context expressly indicates otherwise. As used across the disclosure and in the accompanying claims, the words "include", "has", "include" and all of their grammatical forms have an open, unrestricted meaning that does not exclude additional elements or steps.

<p dir="rtl">5 As used throughout the disclosure, terms such as “first” and “second” are randomly assigned and are intended merely to distinguish between two or more components of a device. It is understood that the words "first" and "second" serve no other purpose and are not any part of the name or explanation of the component, and do not necessarily specify any location or relative position of the component. Moreover, it is understood that the mere use of the terms “first” and “second” does not require the existence of any “third” component, although this possibility is conceivable</p>

<p dir="rtl">ten It falls within the current detection range.</p>

While the disclosure deals with the description in the light of specific models for it, it is clear that many alternatives, modifications, and various forms will become apparent to those skilled in the field in light of the previous description. Accordingly, it is intended to include all these alternatives, modifications, and various forms since they fall within the substance and broad scope of the elements of protection. The present disclosure may include or consist primarily of

<p dir="rtl">fifteen of elements that have been disclosed and can be applied in the absence of an element that has not been disclosed.</p>

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