Recovery system and treatment of hydrocarbon.
Written by Namraj sharma
Cruide oil production and treatment facility oil and gas hydrocarbon Primary recovery system of crude oil.
hydraulic lift systems petroleum or water is taken from a tank and fed to the surface pump. The pressurized fluid is distributed to at least one or more wellheads. For cost-effectiveness, these artificial lift systems are install to provide multiple wellheads during a pad arrangement, a configuration where several wells are drilled near one another . As the pressurized fluid passes into the wellhead and into the downhold pump, a piston pump engages that pushes the produced oil to the surface. Hydraulic submersible pumps create a plus for low-volume producing reservoirs and low-pressure systems.
Conversely, electrical submersible pumps (ESPs) and downhole oil water separators (DOWS) have improved primary production well life for high-volume wells. ESPs are configured to use force to artificially lift oil to the surface from either vertical or horizontal wells. ESPs are useful because they will lift massive volumes of oil. In older fields, as more water is produced, ESPs are preferred for “pumping off” the well to allow maximum boring . DOWS provide a way to eliminate the water handling and disposal risks related to primary boring , by separating oil and gas from produced water at rock bottom of the well. Oil and gas are later pumped to the surface while water related to the method is reinjected into a disposal zone below the surface.
the synthetic lift methods described above, oil could also be produced as long as there's enough nearby reservoir pressure to make flow into the well bore. Inevitably, however, some extent is reached at which commercial quantities not flow into the well. In most cases, but one-third of the oil originally present are often produced by present reservoir pressure alone. In some cases primary production isn't economically possible in the least .
Secondary recovery:
petroleum cruide oil Gas injection and water injection.
When an outsized a part of the petroleum during a reservoir can't be recovered by primary means, a way for supplying extra energy must be found. Most reservoirs have some gas during a miscible state, almost like that of a soda bottled struggling before the gas bubbles are released when the cap is opened. As the reservoir produces under primary conditions, the answer gas escapes, which lowers the pressure of the reservoir. “secondary recovery” is required to reenergize or "build up pressure ” the reservoir. This is accomplished by injecting gas or water into the reservoir to exchange produced fluids and thus maintain or increase the reservoir pressure. When gas alone is injected, it's usually put into the highest of the reservoir, where petroleum normally collect to make a gas cap. Gas injection are often a really effective recovery method in reservoirs where the oil is in a position to flow freely to rock bottom by gravity.
An even more widely practiced secondary recovery method is waterflooding. After being treated to get rid of any material which may interfere with its movement within the reservoir, water is injected through a number of the wells in an oil field. It then moves through the formation, pushing oil toward the remaining production wells. The wells to be used for injecting water are usually located during a pattern which will best push oil toward the assembly wells. Water injection often increases oil recovery to twice that expected from primary means alone. Some oil reservoirs (the East Texas field, for example) are connected to large, active water reservoirs, or aquifers, within the same formation. In such cases it's necessary only to reinject water into the aquifer so as to assist maintain reservoir pressure.
Enhanced recovery for cruise oil production.
Enhanced oil recovery (EOR) is meant to accelerate the assembly of oil from a well. Waterflooding, injecting water to extend the pressure of the reservoir, is one EOR method. Although waterflooding greatly increases recovery from a specific reservoir, it typically leaves up to one-third of the oil in situ . Also, shallow reservoirs containing viscous oil don't respond well to waterflooding. Such difficulties have prompted the industry to hunt enhanced methods of recovering petroleum supplies. Since many of those methods are directed toward oil that's left behind by water injection, they're often mentioned as “tertiary recovery.”
Miscible process.
One method of enhanced recovery is predicated on the injection of gas either at high enough pressure or containing enough petroleum gases within the vapour phase to form the gas and oil miscible. This method leaves little or no oil behind the driving gas, but the relatively low viscosity of the gas can cause the bypassing of huge areas of oil, especially in reservoirs that are not homogeneous. Another enhanced method is meant to recover oil that's left behind by a waterflood by putting a band of soaplike surfactant material before the water. The surfactant creates a really low physical phenomenon between the injected material and therefore the reservoir oil, thus allowing the rock to be “scrubbed” clean. Often, the water behind the surfactant is formed viscous by addition of a polymer so as to stop the water from breaking through and bypassing the surfactant. Surfactant flooding generally works well in noncarbonate rock, but the surfactant material is dear and enormous quantities are required. One method that seems to figure in carbonate rock is carbon dioxide-enhanced oil recovery (CO2 EOR), during which CO2 is injected into the rock, either alone or in conjunction with natural gas. CO2 EOR can greatly improve recovery, but very large quantities of CO2 available at an inexpensive price are necessary. Most of the successful projects of this sort depend upon tapping and transporting (by pipeline) CO2 from underground reservoirs.
In CO2 EOR, CO2 is injected into an oil-bearing reservoir under high . Oil production relies on the mixtures of gases and therefore the oil, which are strongly hooked in to reservoir temperature, pressure, and oil composition. The two main sorts of CO2 EOR processes are miscible and immiscible. Miscible CO2 EOR essentially mixes CO2 with the oil, on which the gas acts as a thinning agent, reducing the oil’s viscosity and freeing it from rock pores. The thinned oil is then displaced by another fluid, like water.
Immiscible CO2 EOR works on reservoirs with low energy, like heavy or low-gravity oil reservoirs. Introducing the CO2 into the reservoir creates three mechanisms that employment together to energise the reservoir to supply oil: viscosity reduction, oil swelling, and dissolved gas drive, where dissolved gas released from the oil expands to push the oil into the well bore.
CO2 EOR sources are predominantly taken from present CO2 reservoirs. Efforts to use industrial CO2 are advancing in light of probably detrimental effects of greenhouse gases (such as carbon dioxide) generated by power and chemical plants, for instance . However, CO2 capture from combustion processes is costlier than CO2 separation from gas reservoirs. Moreover, since plants are rarely located near reservoirs where CO2 EOR could be useful, the storage and pipeline infrastructure that might be required to deliver the CO2 from plant to reservoir would often be too costly to be feasible.
Thermal technology.
As mentioned above, there are many reservoirs, usually shallow, that contain oil which is just too viscous to supply well. Nevertheless, through the appliance of warmth , economical recovery from these reservoirs is feasible . Heavy crude oils, which can have a viscosity up to at least one million times that of water, will show a discount in viscosity by an element of 10 for every temperature increase of 50 °C (90 °F). The most successful thanks to raise the temperature of a reservoir is by the injection of steam. In the most widespread method, called steam cycling, a quantity of steam is injected through a well into a formation and allowed time to condense. Condensation within the reservoir releases the warmth of vaporization that was required to make the steam. Then the same well is put into production. After some water production, heated oil flows into the well bore and is lifted to the surface. Often the cycle are often repeated several times within the same well. A less common method involves the injection of steam from one group of wells while oil is continuously produced from other wells.
An alternate method for heating a reservoir involves in situ combustion—the combustion of a neighborhood of the reservoir oil in place. Large quantities of compressed gas must be injected into the oil zone to support the combustion. The optimal combustion temperature is 500 °C (930 °F). The hot combustion products move through the reservoir to market boring . In situ combustion has not seen widespread use.
Gas cycling process.
Natural gas reservoirs often contain appreciable quantities of heavier hydrocarbons held within the gaseous state. If reservoir pressure is allowed to say no during gas production, these hydrocarbons will condense within the reservoir to liquefied petroleum gas (LPG) and become unrecoverable. to stop a decline in pressure, the liquids are faraway from the produced gas, and therefore the “dry gas” is replace into the reservoir. This process, called gas cycling, is sustained until the optimal quantity of liquids has been recovered. The reservoir pressure is then allowed to say no while the dry gas is produced purchasable . In effect, gas cycling defers the utilization of the gas until the liquids are produced.
Surface equipment for production.
Water often flows into a well along side oil and gas . The well fluids are collected by surface equipment for separation into gas, oil, and water fractions for storage and distribution. The water, which contains salt and other minerals, is typically reinjected into formations that are well separated from freshwater aquifers on the brink of the surface. In many cases it's replace into the formation from which it came. At times, produced water forms an emulsion with the oil or a solid hydrate compound with the gas. In those cases, specially designed treaters are wont to separate the three components. The clean petroleum is shipped to storage at near air pressure . gas is typically piped on to a central gas-processing plant, where “wet gas,” or gas liquids (NGLs), is removed before it's fed to the buyer pipeline. NGLs are primary feedstock for chemical companies in making various plastics and synthetics. Liquid propane gas (a sort of liquefied petroleum gas [LPG]) may be a major factor of NGLs and is that the source of butane and propane fuels.
Storage And Transportation of hydrocarbon.
Offshore production platforms are self-sufficient with reference to power generation and therefore the use of desalinated water for human consumption and operations. In addition, the platforms contain the equipment necessary to process oil before its delivery to the shore by pipeline or to a tanker loading facility. Offshore boring platforms include production separators for separating the produced oil, water, and gas, also as compressors for any associated gas production. These compressors also can be reused for fuel needs in platform operations, like water injection pumps, oil and gas export metering, and main oil line pumps. Onshore operations differs from offshore operations in that more space is typically afforded for storage facilities, as well as general access to and from the facilities.
Almost all storage of petroleum is of relatively short duration, lasting only while the oil or gas is awaiting transport or processing. Crude oil, which is stored at or near air pressure , is typically stored aboveground in cylindrical steel tanks, which can be as large as 30 metres (100 feet) in diameter and 10 metres (33 feet) tall. (Smaller-diameter tanks are used at well sites.) Natural gas and the highly volatile natural gas liquids (NGLs) are stored at higher pressure in steel tanks that are spherical or nearly spherical in shape. Gas is seldom stored, even temporarily, at well sites.
In order to supply supplies when production is less than demand, longer-term storage of oil and gas is usually desirable. This is most frequently done underground in caverns created inside salt domes or in porous rock formations. Underground reservoirs must be surrounded by nonporous rock in order that the oil or gas will stay in situ to be recovered later.
Both petroleum and gas must be transported from cosmopolitan production sites to treatment plants and refineries. Overland movement is largely through pipelines. Crude oil from more isolated wells is collected in tank trucks and brought to pipeline terminals; there's also some transport in specially constructed railroad cars. Pipe utilized in “gathering lines” to hold oil and gas from wells to a central terminal could also be but 5 cm (2 inches) in diameter. Trunk lines, which carry petroleum over long distances, are as large as 120 cm (48 inches). Where practical, pipelines are found to be the safest and most economical method to move petroleum.
Offshore, pipeline infrastructure is usually made from a network of major projects developed by multiple owners. This infrastructure requires a big initial investment, but its operational life may extend up to 40 years with relatively minor maintenance. The lifetime of the typical offshore producing field is 10 years, as compared , and therefore the pipeline investment is shared so on manage capacity increases and reduces as new fields are brought online and old ones fade. A stronger justification for sharing ownership is geopolitical risk. Pipelines are often entangled in geopolitical affairs, requiring lengthy planning and advance negotiations designed to appease many interest groups.
The construction of offshore pipelines differs from that of onshore facilities therein the external pressure to the pipe from water requires a greater diameter relative to pipewall thickness. Main onshore transmission lines range from 50 to more than 140 cm (roughly 20 to more than 55 inches) thick. Offshore pipe is restricted to diameters of about 91 cm (36 inches) in trouble , though some nearshore pipe is capable of slightly wider diameters; nearshore pipe is as wide as major onshore trunk lines. The range of materials for offshore pipelines is more limited than the range for his or her onshore counterparts. Seamless pipe and advanced steel alloys are required for offshore operations so as to face up to high pressures and temperatures as depths increase. Basic pipe designs specialise in three safety elements: safe installation loads, safe operational loads, and survivability in response to varied unplanned conditions, like sudden changes in undersea topography, severe current changes, and earthquakes.
Although barges are wont to transport gathered petroleum from facilities in sheltered inland and coastal waters, overseas transport is conducted in specially designed tanker ships. Tanker capacities vary from less than 100,000 barrels to more than 2,000,000 barrels (4,200,000 to more than 84,000,000 gallons). Tankers that have pressurized and refrigerated compartments also transport compressed liquefied natural gas (LNG) and liquefied petroleum gas (LPG).
Conclusion.
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