CN111394145A - L NG production process method for oilfield associated gas - Google Patents
L NG production process method for oilfield associated gas Download PDFInfo
- Publication number
- CN111394145A CN111394145A CN202010317480.XA CN202010317480A CN111394145A CN 111394145 A CN111394145 A CN 111394145A CN 202010317480 A CN202010317480 A CN 202010317480A CN 111394145 A CN111394145 A CN 111394145A
- Authority
- CN
- China
- Prior art keywords
- gas
- cold
- heavy hydrocarbon
- compressor
- tower
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 238000000034 method Methods 0.000 title claims abstract description 29
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 12
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 117
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 117
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 115
- 239000007789 gas Substances 0.000 claims abstract description 105
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 52
- 239000002994 raw material Substances 0.000 claims abstract description 34
- 230000008569 process Effects 0.000 claims abstract description 18
- 239000003345 natural gas Substances 0.000 claims abstract description 15
- 239000002351 wastewater Substances 0.000 claims abstract description 7
- 239000012071 phase Substances 0.000 claims description 34
- 238000001816 cooling Methods 0.000 claims description 32
- 238000010992 reflux Methods 0.000 claims description 25
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims description 22
- 238000006477 desulfuration reaction Methods 0.000 claims description 16
- 230000023556 desulfurization Effects 0.000 claims description 16
- QWTDNUCVQCZILF-UHFFFAOYSA-N isopentane Chemical compound CCC(C)C QWTDNUCVQCZILF-UHFFFAOYSA-N 0.000 claims description 16
- 239000002808 molecular sieve Substances 0.000 claims description 15
- 238000005261 decarburization Methods 0.000 claims description 14
- URGAHOPLAPQHLN-UHFFFAOYSA-N sodium aluminosilicate Chemical compound [Na+].[Al+3].[O-][Si]([O-])=O.[O-][Si]([O-])=O URGAHOPLAPQHLN-UHFFFAOYSA-N 0.000 claims description 14
- NNPPMTNAJDCUHE-UHFFFAOYSA-N isobutane Chemical compound CC(C)C NNPPMTNAJDCUHE-UHFFFAOYSA-N 0.000 claims description 12
- 239000001294 propane Substances 0.000 claims description 11
- 238000005057 refrigeration Methods 0.000 claims description 11
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims description 10
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 10
- 239000007788 liquid Substances 0.000 claims description 10
- 238000000926 separation method Methods 0.000 claims description 10
- AFABGHUZZDYHJO-UHFFFAOYSA-N dimethyl butane Natural products CCCC(C)C AFABGHUZZDYHJO-UHFFFAOYSA-N 0.000 claims description 8
- 239000003507 refrigerant Substances 0.000 claims description 7
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims description 6
- 239000001282 iso-butane Substances 0.000 claims description 6
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical compound C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 claims description 5
- 239000005977 Ethylene Substances 0.000 claims description 5
- -1 R134a Chemical compound 0.000 claims description 5
- 229910021529 ammonia Inorganic materials 0.000 claims description 5
- 229910052757 nitrogen Inorganic materials 0.000 claims description 5
- 230000000903 blocking effect Effects 0.000 claims description 4
- 238000007710 freezing Methods 0.000 claims description 4
- 230000008014 freezing Effects 0.000 claims description 4
- 239000007791 liquid phase Substances 0.000 claims description 4
- 239000000463 material Substances 0.000 claims description 4
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 claims description 4
- 229910052753 mercury Inorganic materials 0.000 claims description 4
- 230000009467 reduction Effects 0.000 claims description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 4
- 238000003860 storage Methods 0.000 claims description 3
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims description 2
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 claims description 2
- 229910052782 aluminium Inorganic materials 0.000 claims description 2
- 238000010438 heat treatment Methods 0.000 claims description 2
- 230000000087 stabilizing effect Effects 0.000 claims description 2
- 229910052717 sulfur Inorganic materials 0.000 claims description 2
- 239000011593 sulfur Substances 0.000 claims description 2
- 238000005191 phase separation Methods 0.000 abstract description 8
- 239000003921 oil Substances 0.000 description 11
- 150000001412 amines Chemical class 0.000 description 4
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 3
- 238000010521 absorption reaction Methods 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 231100000572 poisoning Toxicity 0.000 description 3
- 230000000607 poisoning effect Effects 0.000 description 3
- 238000001179 sorption measurement Methods 0.000 description 3
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- OFBQJSOFQDEBGM-UHFFFAOYSA-N Pentane Chemical compound CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 238000004134 energy conservation Methods 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 238000005187 foaming Methods 0.000 description 2
- CRSOQBOWXPBRES-UHFFFAOYSA-N neopentane Chemical compound CC(C)(C)C CRSOQBOWXPBRES-UHFFFAOYSA-N 0.000 description 2
- 238000004064 recycling Methods 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 1
- 239000003463 adsorbent Substances 0.000 description 1
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 1
- 238000009835 boiling Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000005262 decarbonization Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011978 dissolution method Methods 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 238000001704 evaporation Methods 0.000 description 1
- 230000008020 evaporation Effects 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 1
- 239000003498 natural gas condensate Substances 0.000 description 1
- 239000002343 natural gas well Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 239000000741 silica gel Substances 0.000 description 1
- 229910002027 silica gel Inorganic materials 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Images
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/12—Liquefied petroleum gas
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
Landscapes
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Geology (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Physics & Mathematics (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Separation By Low-Temperature Treatments (AREA)
Abstract
The invention provides a process method for producing L NG (natural gas) from oilfield associated gas, which is characterized by comprising a raw material gas buffer tank, a raw material gas compressor, a raw material gas cooler and the like, wherein external raw material gas enters the raw material gas buffer tank through a conveying pipeline, the raw material gas buffer tank is respectively connected with an external wastewater output pipeline, the raw material gas compressor and a stable light hydrocarbon tower through the conveying pipeline, the raw material gas compressor is connected with a three-phase separation tank through the conveying pipeline, and the raw material gas cooler is installed on the conveying pipeline.
Description
Technical Field
The invention relates to the field of oilfield exploitation, in particular to a L NG production process method of oilfield associated gas.
Background
During the process of crude oil recovery, relatively light components such as methane, ethane, propane, n-butane, isobutane, n-pentane, isopentane, neopentane and the like, which are generally dissolved in crude oil, are separated out, and are called oilfield associated gas and are another source of natural gas.
Because associated gas is relatively dispersed and has high recycling difficulty, the existing associated gas recycling technology mainly recycles part of light hydrocarbon, the rest dry gas is burnt and discharged or generates electricity, and the process technology for gasifying the associated gas into L NG is vacant, so that the serious waste of resources is caused.
Through the rapid development of the petroleum industry in recent years, governments pay more and more attention to the energy conservation and emission reduction of oil enterprises and the degree of environmental protection. As an important ring for energy conservation, emission reduction, production expansion and efficiency improvement, if the associated gases are all recycled, the method is not only beneficial to solving the environmental problem, but also can increase the economic benefit, and has important significance for enterprises and national sustainable green development.
The process of liquefying L NG of natural gas generally refers to well mouth gas or pipeline gas of a natural gas field, the gas quality composition is stable in gas amount and small in fluctuation, and natural gas is directly decarbonized, desulfurized, dehydrated and demercurated and then enters a cold box for liquefaction.
For heavy hydrocarbon, adsorption separation methods such as adsorption separation method, isopentane dissolution method and cryogenic separation method are generally adopted, and solid with a porous structure such as silica gel, molecular sieve and activated carbon are mainly used as adsorbents, so that hydrocarbon gas is separated according to the difference of adsorption capacities of hydrocarbon components.
The isopentane dissolving method is characterized in that a washing tower is added behind a heavy hydrocarbon separation tank, and the heavy hydrocarbon in the dissolved natural gas is absorbed by utilizing the principle of similarity and intermiscibility.
The cryogenic separation method mainly utilizes the different boiling points of hydrocarbon components to achieve the purpose of gas-liquid separation. The natural gas is cooled to a low temperature below the dew point temperature of the hydrocarbon to obtain condensate partially rich in C5 + hydrocarbons, and the condensate is separated and removed from the heavy hydrocarbon.
Disclosure of Invention
According to the technical problems, the invention adopts stable light hydrocarbon, combines low-temperature rectification and refrigeration technologies, can effectively adapt to the working conditions of different gas qualities of the oilfield associated gas, solves the problems of oil carrying of amine liquid of a decarburization and desulfurization system, foaming flooding in an absorption tower, molecular sieve poisoning and freezing and blocking of a cold box in the natural gas treatment process, and provides necessary conditions for liquefaction of the oilfield associated gas.
The invention provides a L NG process method for producing oilfield associated gas, which comprises the following specific process flows that raw material gas is pressurized to 40-50 bar by a three-stage booster set, is cooled to 45 ℃ by an air cooler, then enters a precooling heat exchanger to be cooled to 15-20 ℃, enters a three-phase separator to be separated, gas phase enters a gas phase treatment unit, oil phase enters a stable light hydrocarbon tower, a reboiler is arranged at the bottom of the tower, heat-conducting oil or steam is used as a heat source, the temperature is controlled to be 100-140 ℃, light components are evaporated from the top of the tower to enter a raw material gas tank through heating, and water phase enters a sewage tank;
gas phase coming from the three-phase separator sequentially passes through a decarburization and desulfurization system, a molecular sieve dryer and a demercuration tank;
the treated natural gas firstly enters the middle part of a heavy hydrocarbon tower, light components of methane and ethane are separated out through rectification, the heavy hydrocarbon tower is provided with a reboiler, heat conducting oil or steam is used as a heat source, the temperature is controlled to be 100-140 ℃, a gas phase on the top of the heavy hydrocarbon tower enters a cooling box to be cooled to the temperature of-40 ℃ to-75 ℃, the gas phase enters a heavy hydrocarbon separation tank, the gas phase from the heavy hydrocarbon tank is continuously subjected to deep cooling and is cooled to the temperature of-155 ℃, throttling pressure reduction is carried out to the temperature of 1.5-2 bar, the liquid phase from the heavy hydrocarbon tank enters an L NG storage tank, the liquid phase from the heavy hydrocarbon tank returns to the top of the heavy hydrocarbon tower as reflux through a heavy hydrocarbon pump, materials at the bottom of the heavy hydrocarbon tower and materials at the bottom of a stabilizing tower.
A L NG process method for producing oilfield associated gas comprises a raw material gas buffer tank, a raw material gas compressor, a raw material gas cooler, a three-phase separation tank, a stable light hydrocarbon tower reboiler, a decarburization desulfurization system, a molecular sieve dryer, a demercuration tank, a heavy hydrocarbon tower, a reboiler, a low temperature gas-liquid separator, a heavy hydrocarbon reflux pump, a cold box, a pre-cooling compressor unit condenser, a main cold compressor unit and a main cold compressor unit condenser, wherein external raw material gas enters the raw material gas buffer tank through a conveying pipeline, the raw material gas buffer tank is respectively connected with an external wastewater output pipeline, a raw material gas compressor and a stable light hydrocarbon tower through a conveying pipeline, the raw material gas compressor is connected with the three-phase separation tank through a conveying pipeline, the raw material gas cooler is installed on the conveying pipeline, the three-phase separation tank is connected with the desulfurization system, an external wastewater output pipeline and the stable light hydrocarbon tower, the stable light hydrocarbon tower is also respectively connected with a mixed hydrocarbon conveying pipeline, a stable light hydrocarbon tower, the decarburization desulfurization system is connected with the heavy hydrocarbon tower drier unit through a NG pipeline and a decarburization pipeline, the heavy hydrocarbon reflux pump is connected with the main cold hydrocarbon compressor unit, the heavy hydrocarbon reflux pump is connected with the cold hydrocarbon reflux pump and the main cold hydrocarbon compressor unit, the heavy hydrocarbon reflux pump is connected with the heavy hydrocarbon reflux condenser, the cold hydrocarbon compressor unit and the heavy hydrocarbon reflux condenser, the cold hydrocarbon reflux compressor unit is connected with the cold hydrocarbon reflux compressor unit through a cold hydrocarbon reflux pump L, the cold hydrocarbon compressor unit, the cold hydrocarbon reflux compressor unit, the.
The cold box, the pre-cooling compressor set and the condenser of the pre-cooling compressor set are connected through pipelines to form a closed pre-cooling system, the cold box, the main cold compressor set and the condenser of the main cold compressor set are connected through pipelines to form a closed cryogenic system, a valve is arranged between the cold box and the condenser of the pre-cooling compressor set, a valve is arranged between the cold box and the condenser of the main cold compressor set, the pre-cooling compressor set is a single cold medium and provides a cold source for a high-temperature section, the pre-cooling compressor set comprises propane, ammonia, R134a, R22 and R23, the refrigeration temperature range is (-10 ℃ to-40 ℃, the main cold compressor set is a mixed cold medium and provides a cold source for a cryogenic section, and the refrigeration temperature range is-80 ℃ to-180 ℃ and comprises the combination of different proportions of nitrogen, methane, propane, ethylene, isobutane and isopentane.
The cold energy of the cold box is provided by a precooling compressor and a main cold compressor.
The precooling compressor is a cold source which is provided with a high-temperature section by a single cold medium, the cold source comprises propane, ammonia, R134a, R22 and R23, and the refrigeration temperature range is-10 ℃ to-40 ℃.
The main cold compressor is a mixed refrigerant medium and provides a cryogenic section cold source, the cold source comprises a combination of nitrogen, methane, propane, ethylene, isobutane and isopentane in different proportions, and the refrigeration temperature range is-80 ℃ to-180 ℃.
The gas sequentially passes through the decarburization and desulfurization system, the molecular sieve dryer and the demercuration tank, the content of CO2 in the natural gas is reduced to be within 30PPM, the sulfur content is reduced to be within 3PPM, the water content is reduced to be within 1PPM, and the mercury content is reduced to be within 0.01ug/m3, so that freezing and blocking of the cold box and corrosion of an aluminum plate fin heat exchanger in the cold box by mercury are prevented, and the damage to the cold box is avoided.
The invention has the beneficial effects that: the invention is suitable for oil field associated gas, natural gas well head gas, natural gas condensate gas and crude oil tank flash evaporation gas. The invention adds the stable light hydrocarbon tower for removing most of heavy hydrocarbon, reduces the influence of the heavy hydrocarbon on a rear decarburization desulfurization system and a molecular sieve dryer, solves the problems of oil foaming and molecular sieve poisoning failure of the amine liquid absorption tower, and lightens the loads of a cold box and a refrigeration compressor.
The heavy hydrocarbon tower of the invention is a rectifying tower and is divided into a rectifying section and a stripping section. The treated oilfield associated gas firstly enters the middle part of a heavy hydrocarbon tower, the heavy hydrocarbon is gathered at the bottom of the tower by the reflux of low-temperature liquid at the top of the tower and is extracted from a tower kettle, and the heavy hydrocarbon in the associated gas is prevented from entering a cold box again to cause the freezing and blocking of the cold box; the tower bottom is heated by a reboiler to separate methane and ethane, the gas phase at the tower top almost does not contain C3 and above components, and the tower bottom contains trace ethane.
The invention is provided with two groups of refrigerating units, the cold energy is provided by two groups of refrigerating units with different grades, the refrigerating unit with the pre-refrigerating compressor is a single refrigerant medium which provides a cold source at a high temperature section, the cold source comprises propane, ammonia, R134a, R22, R23 and the like, the refrigerating temperature range is-10 ℃ to-40 ℃, the main refrigerating compressor is a mixed refrigerant medium which provides a cold source at a deep refrigerating section, the cold source comprises nitrogen, methane, propane, ethylene, isobutane, isopentane and the like which are combined in different proportions, and the refrigerating temperature range is-80 ℃ to-180 ℃. The two groups of refrigerating units can deal with raw materials with different compositions, and have stable operation and high adaptability.
The stable light hydrocarbon tower is respectively connected with the heavy hydrocarbon tower, the mixed hydrocarbon conveying pipeline and the stable light hydrocarbon tower reboiler, and the design of the stable light hydrocarbon tower can remove most of heavy hydrocarbons in the face of raw materials rich in C3 and above components, so that the load of a refrigerating device and the disposal load of the heavy hydrocarbon tower are effectively reduced. The problems that the amine liquid carries oil and the amine liquid in the absorption tower foams can be avoided; the stable light hydrocarbon tower removes benzene and aromatic hydrocarbons in advance, avoids the poisoning problem of the molecular sieve drying tower, and prolongs the service life of the molecular sieve. The purified natural gas firstly enters the heavy hydrocarbon separation tower to remove heavy hydrocarbon, and the gas phase enters the liquefaction cold box, so that the blockage of the liquefaction cold box can be effectively prevented. Further remove heavy hydrocarbon, reduce the cold box and freeze stifled risk.
Drawings
FIG. 1 is a schematic view of the structure of the present invention.
As shown in the figure: 1-raw gas buffer tank; 2-a feed gas compressor; 3-raw gas cooler; 4-a three-phase separation tank; 5-stable light hydrocarbon tower; 6-stable light hydrocarbon tower reboiler; 7-a decarbonization and desulfurization system; 8-molecular sieve dryer; 9-demercuration tank; a 10-heavy hydrocarbon column; 11-a reboiler; 12-low temperature gas-liquid separator; 13-heavy hydrocarbon reflux pump; 14-a cold box; 15-a pre-refrigeration compressor train; 16-a pre-cooling compressor set condenser; 17-a primary cold compressor train; 18-main cold compressor train condenser.
Detailed Description
Example 1
The invention provides a process method for producing L NG by oilfield associated gas, which comprises a raw material gas buffer tank, a raw material gas compressor, a raw material gas cooler, a three-phase separation tank, a stable light hydrocarbon tower reboiler, a decarburization and desulfurization system, a molecular sieve dryer, a demercuration tank, a heavy hydrocarbon tower, a reboiler, a low-temperature gas-liquid separator, a heavy hydrocarbon reflux pump, a cold box, a pre-cold compressor set condenser, a main cold compressor set condenser, a raw material gas enters the raw material gas buffer tank through a conveying pipeline, the raw material gas buffer tank is respectively connected with a waste water output outdoor pipeline through a conveying pipeline, the raw material gas compressor and the stable light hydrocarbon tower, the raw material gas compressor is connected with the stable light hydrocarbon tower through a conveying pipeline and a three-phase separation tank, the raw material gas cooler is installed on the conveying pipeline, the three-phase separation tank is connected with a decarburization and desulfurization system through a conveying pipeline, a waste water output outdoor pipeline, the stable light hydrocarbon tower is also respectively connected with a mixed hydrocarbon conveying pipeline, the stable light hydrocarbon tower reboiler, the desulfurization system is connected with the main cold compressor set condenser through a conveying pipeline 6780-cold compressor set, the cold compressor set condenser and a cold compressor set, the cold compressor set condenser are connected with a low-cold compressor set, the cold compressor set condenser, the cold compressor set is connected with the cold compressor set condenser through a low-cold compressor set.
Example 2
The invention relates to a L NG production process method of oilfield associated gas, which comprises the following specific application methods:
the method comprises the steps of pressurizing feed gas to 40-50 bar through a three-stage booster set, cooling the feed gas to 45 ℃ through an air cooler, then cooling the feed gas to 15-20 ℃ through a precooling heat exchanger, separating the feed gas through a three-phase separator, feeding the gas phase into a gas phase treatment unit, feeding the oil phase into a stable light hydrocarbon tower, arranging a reboiler at the tower bottom, using heat conduction oil or steam as a heat source, controlling the temperature of the reboiler at 100-140 ℃, feeding the gas phase from the three-phase separator through a decarburization desulfurization system, a molecular sieve dryer and a demercuration tank, feeding the treated natural gas into the middle part of a heavy hydrocarbon tower, separating light components of methane and ethane through rectification, arranging the reboiler in the heavy hydrocarbon tower, using the heat conduction oil or the steam as the heat source, controlling the temperature of the heavy hydrocarbon tower to be 100-140 ℃, feeding the gas phase at the tower top of the heavy hydrocarbon tower into a cooling box, cooling the gas phase to-40-75 ℃, feeding the gas phase into a heavy hydrocarbon separation tank, cooling the gas phase from the heavy hydrocarbon tank continuously, throttling the heavy hydrocarbon tower to about-155 ℃, reducing the pressure to 1.5-2 bar, feeding the heavy hydrocarbon tank into a L bar, feeding the heavy hydrocarbon tank, further processing the heavy hydrocarbon tower, and returning the heavy hydrocarbon mixture into a heavy hydrocarbon storage.
The foregoing shows and describes the general principles and broad features of the present invention and advantages thereof. While the invention has been described with respect to the above embodiments, it will be understood by those skilled in the art that the invention is not limited to the above embodiments, which are described in the specification and illustrated only to illustrate the principles of the invention, but that various changes and modifications may be made without departing from the spirit and scope of the invention as defined by the appended claims. The scope of the invention is defined by the appended claims and equivalents thereof.
Claims (7)
1. A process method for producing L NG from oilfield associated gas is a process method for producing L NG from oilfield associated gas, and is characterized in that the specific application method comprises the following steps:
the method comprises the following steps that a raw material gas is pressurized to 40-50 bar through a three-stage booster set, the raw material gas is cooled to 45 ℃ through an air cooler, then enters a precooling heat exchanger to be cooled to 15-20 ℃, enters a three-phase separator to be separated, a gas phase enters a gas phase treatment unit, an oil phase enters a stable light hydrocarbon tower, a reboiler is arranged at the bottom of the tower, heat conducting oil or steam is used as a heat source, the temperature is controlled to be 100-140 ℃, light components are evaporated from the top of the tower to enter a raw material gas tank through heating, and a water;
gas phase coming from the three-phase separator sequentially passes through a decarburization and desulfurization system, a molecular sieve dryer and a demercuration tank;
the treated natural gas firstly enters the middle part of a heavy hydrocarbon tower, light components of methane and ethane are separated out through rectification, the heavy hydrocarbon tower is provided with a reboiler, heat conducting oil or steam is used as a heat source, the temperature is controlled to be 100-140 ℃, a gas phase on the top of the heavy hydrocarbon tower enters a cooling box to be cooled to the temperature of-40 ℃ to-75 ℃, the gas phase enters a heavy hydrocarbon separation tank, the gas phase from the heavy hydrocarbon tank is continuously subjected to deep cooling and is cooled to the temperature of-155 ℃, throttling pressure reduction is carried out to the temperature of 1.5-2 bar, the liquid phase from the heavy hydrocarbon tank enters an L NG storage tank, the liquid phase from the heavy hydrocarbon tank returns to the top of the heavy hydrocarbon tower as reflux through a heavy hydrocarbon pump, materials at the bottom of the heavy hydrocarbon tower and materials at the bottom of a stabilizing tower.
2. The process for producing L NG in oilfield associated gas according to claim 1, wherein the cold energy of the cold box is provided by a pre-cooling compressor and a main cold compressor.
3. The process for producing L NG in oilfield associated gas according to claim 1, wherein the pre-cooling compressor is a single refrigerant providing a heat sink for high temperature section, the heat sink comprises propane, ammonia, R134a, R22 and R23, and the refrigeration temperature is in the range of-10 ℃ to-40 ℃.
4. The L NG process for producing associated gas in oil field according to claim 1, wherein said main cold compressor is a mixed refrigerant medium providing a cryogenic section cold source, said cold source comprises a combination of different ratios of nitrogen, methane, propane, ethylene, isobutane, isopentane, and the refrigeration temperature ranges from-80 ℃ to-180 ℃.
5. The process for producing L NG in oilfield associated gas according to claim 1, wherein the gas passes through the decarburization and desulfurization system, the molecular sieve dryer and the demercuration tank in sequence, so that the content of CO2 in the natural gas is reduced to be within 30PPM, the content of sulfur is reduced to be within 3PPM, the content of water is reduced to be within 1PPM, the content of mercury is reduced to be within 0.01ug/m3, freezing and blocking of the cooling box are prevented, and the mercury corrodes an aluminum plate-fin heat exchanger in the cooling box to cause damage of the cooling box.
6. A process of L NG in oilfield associated gas production according to claim 1, wherein the specific process system comprises a raw gas buffer tank, a raw gas compressor, a raw gas cooler, a three-phase separator tank, a stable light hydrocarbon tower reboiler, a decarburization desulfurization system, a molecular sieve dryer, a demercuration tank, a heavy hydrocarbon tower, a reboiler, a low temperature gas-liquid separator, a heavy hydrocarbon reflux pump, a cold box, a pre-cooling compressor unit condenser, a main cold compressor unit condenser, wherein the external raw gas enters the raw gas buffer tank through a delivery pipe, the raw gas buffer tank is connected to a waste water output outdoor pipeline, the raw gas compressor, and the stable heavy hydrocarbon tower reboiler through a delivery pipe, the raw gas compressor is connected to the raw gas compressor through a delivery pipe and a three-phase separator tank, the raw gas cooler is installed on the delivery pipe, the three-phase separator tank is connected to a decarburization desulfurization system, a waste water output outdoor pipeline, a stable heavy hydrocarbon delivery pipe, the stable hydrocarbon delivery pipe is connected to the heavy hydrocarbon delivery pipe, the heavy hydrocarbon delivery pipe and the heavy hydrocarbon reflux pump, the cold hydrocarbon reflux condenser is connected to the heavy hydrocarbon reflux pump, the cold hydrocarbon compressor and the heavy hydrocarbon reflux condenser, the cold compressor unit is connected to the light hydrocarbon reflux pump through a delivery pipe L, the cold hydrocarbon reflux compressor unit is connected to the heavy hydrocarbon reflux compressor and the cold hydrocarbon reflux compressor unit.
7. The process method of L NG for oilfield associated gas according to claim 6, wherein the cold box, the pre-cooling compressor set and the condenser of the pre-cooling compressor set are connected by a pipeline to form a closed pre-cooling system, the cold box, the condenser of the main cooling compressor set and the condenser of the main cooling compressor set are connected by a pipeline to form a closed cryogenic system, a valve is installed between the cold box and the condenser of the pre-cooling compressor set, a valve is installed between the cold box and the condenser of the main cooling compressor set, the pre-cooling compressor set is a single refrigerant medium providing a cold source of a high temperature section and comprises propane, ammonia, R134a, R22 and R23, the refrigeration temperature range is (-10 ℃ to-40 ℃), the main cooling compressor set is a mixed refrigerant medium providing a cryogenic section cold source and comprises a combination of different proportions of nitrogen, methane, propane, ethylene, isobutane and isopentane, and the refrigeration temperature range is-80 ℃ to-180 ℃.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010317480.XA CN111394145A (en) | 2020-04-21 | 2020-04-21 | L NG production process method for oilfield associated gas |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010317480.XA CN111394145A (en) | 2020-04-21 | 2020-04-21 | L NG production process method for oilfield associated gas |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN111394145A true CN111394145A (en) | 2020-07-10 |
Family
ID=71437169
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010317480.XA Pending CN111394145A (en) | 2020-04-21 | 2020-04-21 | L NG production process method for oilfield associated gas |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111394145A (en) |
Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112226259A (en) * | 2020-10-20 | 2021-01-15 | 中海石油(中国)有限公司 | High-efficient compact marine oil field associated gas recycle device |
| CN112831349A (en) * | 2020-12-11 | 2021-05-25 | 中国石油天然气股份有限公司 | Method for improving utilization efficiency of associated gas of oil field operation station |
| CN115701449A (en) * | 2021-08-02 | 2023-02-10 | 中国石油天然气股份有限公司 | Liquefied petroleum gas production system meeting copper sheet corrosion requirements |
| CN117244270A (en) * | 2023-11-20 | 2023-12-19 | 新疆凯龙清洁能源股份有限公司 | Recycling method of sulfur-containing low-pressure alkane gas |
Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB560193A (en) * | 1941-01-02 | 1944-03-24 | Standard Oil Dev Co | Improvements in or relating to the fractionation of mixtures of gaseous hydrocarbons |
| US5992175A (en) * | 1997-12-08 | 1999-11-30 | Ipsi Llc | Enhanced NGL recovery processes |
| CN104279838A (en) * | 2013-07-09 | 2015-01-14 | 王建基 | Oilfield associated gas stable mixed hydrocarbon recycling and natural gas liquefaction combined technology |
| CN111004657A (en) * | 2019-12-11 | 2020-04-14 | 中国天辰工程有限公司 | Method for comprehensively utilizing oilfield associated gas |
| CN212833654U (en) * | 2020-04-21 | 2021-03-30 | 天津深蓝化工技术有限公司 | Reaction system for producing LNG (liquefied Natural gas) from oilfield associated gas |
-
2020
- 2020-04-21 CN CN202010317480.XA patent/CN111394145A/en active Pending
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB560193A (en) * | 1941-01-02 | 1944-03-24 | Standard Oil Dev Co | Improvements in or relating to the fractionation of mixtures of gaseous hydrocarbons |
| US5992175A (en) * | 1997-12-08 | 1999-11-30 | Ipsi Llc | Enhanced NGL recovery processes |
| CN104279838A (en) * | 2013-07-09 | 2015-01-14 | 王建基 | Oilfield associated gas stable mixed hydrocarbon recycling and natural gas liquefaction combined technology |
| CN111004657A (en) * | 2019-12-11 | 2020-04-14 | 中国天辰工程有限公司 | Method for comprehensively utilizing oilfield associated gas |
| CN212833654U (en) * | 2020-04-21 | 2021-03-30 | 天津深蓝化工技术有限公司 | Reaction system for producing LNG (liquefied Natural gas) from oilfield associated gas |
Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112226259A (en) * | 2020-10-20 | 2021-01-15 | 中海石油(中国)有限公司 | High-efficient compact marine oil field associated gas recycle device |
| CN112831349A (en) * | 2020-12-11 | 2021-05-25 | 中国石油天然气股份有限公司 | Method for improving utilization efficiency of associated gas of oil field operation station |
| CN115701449A (en) * | 2021-08-02 | 2023-02-10 | 中国石油天然气股份有限公司 | Liquefied petroleum gas production system meeting copper sheet corrosion requirements |
| CN115701449B (en) * | 2021-08-02 | 2024-10-01 | 中国石油天然气股份有限公司 | Liquefied petroleum gas production system meeting copper sheet corrosion requirement |
| CN117244270A (en) * | 2023-11-20 | 2023-12-19 | 新疆凯龙清洁能源股份有限公司 | Recycling method of sulfur-containing low-pressure alkane gas |
| CN117244270B (en) * | 2023-11-20 | 2024-02-13 | 新疆凯龙清洁能源股份有限公司 | Recycling method of sulfur-containing low-pressure alkane gas |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN111394145A (en) | L NG production process method for oilfield associated gas | |
| USRE39826E1 (en) | Comprehensive natural gas processing | |
| CN104419464B (en) | Dry gas recovery system and dry gas recovery method for refinery plant | |
| CN109749780B (en) | Device and method for recovering carbon dioxide in refinery dry gas by oil absorption and compression condensation method | |
| SG174568A1 (en) | Process for natural gas liquefaction | |
| CN106256813B (en) | A kind of separation and recovery method of Fischer-Tropsch process exhaust | |
| CN101625190A (en) | Mixed refrigerant re-circulated liquefaction process for precooling coalbed methane (CBM) by residual pressure of pressure swing adsorption (PSA) | |
| CN212833654U (en) | Reaction system for producing LNG (liquefied Natural gas) from oilfield associated gas | |
| CN106753628A (en) | A kind of method and device of coke-stove gas LNG combined production of methanol | |
| CN104419465B (en) | A kind of oil refinery dry gas recovery system and dry-gas recovery method | |
| CN102438726A (en) | Method for processing a natural load gas for obtaining a natural processed gas and a reduction in c5+ hydrocarbons, and associated installation | |
| CN101113365A (en) | Process for recovering lighter hydrocarbons from refinery dry gas | |
| CN104419466B (en) | A kind of oil refinery dry gas recovery system and dry-gas recovery method | |
| CN214735563U (en) | System for producing light hydrocarbon and LNG (liquefied Natural gas) from oilfield associated gas | |
| CN211946916U (en) | Oil field associated gas light hydrocarbon recovery system | |
| CN116839310A (en) | Process method for preparing food-grade liquid carbon dioxide by utilizing decarburization exhaust gas of LNG (liquefied Natural gas) plant | |
| CN211847817U (en) | Associated gas light hydrocarbon recovery system for dry gas low-pressure expansion oil field | |
| CN112980490B (en) | Light hydrocarbon recovery system for dry gas low-pressure expansion oilfield associated gas and use method | |
| CN211771091U (en) | Open refrigeration oil field associated gas light hydrocarbon recovery system | |
| CN112980489B (en) | Process method for recycling light hydrocarbons of associated gas of open refrigeration oilfield | |
| CN106500458B (en) | Pre-cooling type natural gas liquefaction process and system | |
| JP5552160B2 (en) | Hydrocarbon gas treatment | |
| CN101290184B (en) | Chemical industry tail gas liquefied separation method and equipment | |
| CN112812806B (en) | Process and system for producing light hydrocarbon and LNG (liquefied Natural gas) from oilfield associated gas | |
| CN112980491B (en) | Oilfield associated gas light hydrocarbon recovery system |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |