CN1342742A - Deep cooling process for separating natural gas with CO2 content less than 10% - Google Patents
Deep cooling process for separating natural gas with CO2 content less than 10% Download PDFInfo
- Publication number
- CN1342742A CN1342742A CN 01134260 CN01134260A CN1342742A CN 1342742 A CN1342742 A CN 1342742A CN 01134260 CN01134260 CN 01134260 CN 01134260 A CN01134260 A CN 01134260A CN 1342742 A CN1342742 A CN 1342742A
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- China
- Prior art keywords
- natural gas
- gas
- ethane
- deep cooling
- cooling process
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 52
- 238000000034 method Methods 0.000 title claims abstract description 27
- 239000003345 natural gas Substances 0.000 title claims abstract description 26
- 238000001816 cooling Methods 0.000 title claims abstract description 11
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 38
- 239000007789 gas Substances 0.000 claims abstract description 28
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims abstract description 18
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims abstract description 16
- 239000001294 propane Substances 0.000 claims abstract description 9
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 6
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims abstract description 6
- 239000007788 liquid Substances 0.000 claims abstract description 6
- 238000007710 freezing Methods 0.000 claims abstract description 4
- 235000011089 carbon dioxide Nutrition 0.000 claims description 14
- 235000009508 confectionery Nutrition 0.000 claims description 14
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 12
- 239000001569 carbon dioxide Substances 0.000 claims description 11
- 239000002253 acid Substances 0.000 claims description 7
- 238000010521 absorption reaction Methods 0.000 claims description 5
- 241000282326 Felis catus Species 0.000 claims description 3
- 238000005265 energy consumption Methods 0.000 abstract description 6
- 230000008901 benefit Effects 0.000 abstract description 3
- 230000003247 decreasing effect Effects 0.000 abstract 1
- 230000008014 freezing Effects 0.000 abstract 1
- 238000005516 engineering process Methods 0.000 description 7
- 238000002347 injection Methods 0.000 description 4
- 239000007924 injection Substances 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 150000001412 amines Chemical class 0.000 description 2
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 230000003750 conditioning effect Effects 0.000 description 2
- 230000018044 dehydration Effects 0.000 description 2
- 238000006297 dehydration reaction Methods 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- CRVGTESFCCXCTH-UHFFFAOYSA-N methyl diethanolamine Chemical compound OCCN(C)CCO CRVGTESFCCXCTH-UHFFFAOYSA-N 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 239000000470 constituent Substances 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000012467 final product Substances 0.000 description 1
- 238000005187 foaming Methods 0.000 description 1
- 238000001802 infusion Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 230000000192 social effect Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
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- Gas Separation By Absorption (AREA)
- Carbon And Carbon Compounds (AREA)
Abstract
A process for separating CO2, hydrogen sulfide, ethane and propane from natural gas features use of a deep cooling apparatus and control of system pressure and temp. so that the condensate oil field can be exploited under the pressure higher than dew point. Its advantages are no freezing CO2, high output rate of 96% for ethane or 99% of propane, low investment, low energy consumption decreased by 50%, and improving recovering environment of oil or gas reservoir stratum and raising the condensate liquid output.
Description
The present invention relates to a kind of deep cooling separating method of high-content carbonic acid gas Sweet natural gas.
Traditional Sweet natural gas cryogenic technology, constitute by depickling unit, cryogenic unit two-step, when require ethane recovery reach 80%, when the propane yield reaches 95%, surpass 2% (mol%) if enter the content of carbonic acid gas in the unstripped gas of Sweet natural gas cryogenic unit, then carbonic acid gas will freeze in system; In recent years the content of the carbon dioxide in natural of some regional development＞8% (mol%), hydrogen sulfide＞100ppm, for guaranteeing that traditional cryogenic technology system can normally move, must with the CO2 removal in the raw natural gas be earlier behind the depickling unit, carry out the Sweet natural gas low temperature separation process again.Amine at present commonly used absorbs deacidifying process, to the Sweet natural gas of carbon dioxide content higher (6%～10%), generally adopts selectivity solution such as methyldiethanolamine (MEDA) absorption deacidifying process preferably, with the CO in the raw natural gas
2And H
2S removes together, and then carries out sub-zero treatment.Existing technology weak point mainly be: 1, carbon dioxide gas does not have the source, needs through art breading such as dehydration, compressions if be used for re-injection, and complex process, investment and energy consumption are very big; 2, the corrodibility to system is bigger; When 3, depickling system moved, the heavy hydrocarbon that the Sweet natural gas condensation goes out accumulated in system, will cause foaming in the absorption tower, destroyed the operation balance of system.
The objective of the invention is to avoid weak point of the prior art, and a kind of carbonic acid gas that need not to remove in the Sweet natural gas is provided, cryogenic system can not freeze, and energy consumption is low, the carbon dioxide content of less investment is less than 10% deep cooling process for separating natural gas method.
Can take following technical scheme to realize purpose.
Carbon dioxide content is less than 10% deep cooling process for separating natural gas, and method is that the above component of carbonic acid gas, hydrogen sulfide, ethane and propane is all isolated from unstripped gas through the Sweet natural gas cryogenic unit.
According to the characteristics of high-content carbonic acid gas Sweet natural gas, " single stage method gas conditioning technology " its process of employing is that carbonic acid gas, hydrogen sulfide, ethane and propane component are all isolated from unstripped gas through the Sweet natural gas cryogenic unit, does not produce CO
2Freeze, utilize the variation of demethanizing tower or deethanizing column top gaseous component, the minimum temperature of control device is higher than CO
2Freezing temperature, it is stifled that system can not frozen, and the yield of ethane or propane reaches more than 96%.Technological process confuses ethane and acid gas to close and annotates in the stratum.System's equipment therefor is the gas conditioning general-purpose equipment.
The relative prior art of the technical program has following advantage and effect:
1) with the backflow absorption liquid of deethanizing cat head liquefaction of gases as light ends tower, the pressure and temperature of Controlling System, 6%～10% the carbonic acid gas that exists in the cryogenic system technological process can not freeze.2) ethane recovery reaches 96%; The propane yield reaches 99%.3) compare with traditional deacidifying process, investment reduces 1/3rd; The energy consumption for the treatment of processes reduces more than 50% and investment descends significantly.4) mixed gas of ethane and carbonic acid gas etc. is the good source of the gas of the condensate oil gas field miscible-phase displacement, can guarantee effectively that the condensate oil gas field exploits being higher than under its dew-point pressure condition; When the condensate oil gas field is being higher than when exploiting under its dew-point pressure condition, can reduce condensed liquid isolating in the stratum to greatest extent, guarantee extraction condensate gas heavy constituent to greatest extent.Utilize the mixed gas of ethane, carbonic acid gas etc. that the dew-point pressure that the miscible-phase displacement also helps the reduction condensate gas is carried out in the condensate oil gas field, thereby further improve the formation production environment of hydrocarbon-bearing pool, improve the output of condensed liquid, create an optimum exploitation circulation.Acid gas re-injections such as carbonic acid gas also there is great social effect to environment protection.The dehydrated liquefaction of acid gas after this technological process is handled is gone into the stratum with infusion and is got final product, and the re-injection pump horsepower only has 150 kilowatts, and economic benefit is very remarkable.With the depickling of usefulness amine deacidifying process, with acid gas compression and dehydration, utilize the technology of compressor re-injection to compare, its energy consumption is the latter's 1/10th.5) acid gas in the ethane separates with less energy consumption and investment and can realize, this technology will reclaim 96% ethane and be recycled into and go in the stratum from Sweet natural gas, can wait until from now on and exploit.
In conjunction with the accompanying drawings, embodiment is described in further detail the content of the technical program.
Fig. 1 is the process flow diagram of traditional Sweet natural gas cryogenic technology;
Fig. 2 is a carbon dioxide content less than 10% deep cooling process for separating natural gas schema.
Embodiment 1, carbon dioxide content are less than 10% deep cooling process for separating natural gas, and its flow process is that the above component of carbonic acid gas, hydrogen sulfide, ethane and propane is all isolated from unstripped gas through the Sweet natural gas cryogenic unit.As shown in Figure 2.
Embodiment 2, carbon dioxide content are less than 10% deep cooling process for separating natural gas, based on embodiment 1, utilize the variation of demethanizing tower or deethanizing column top gaseous component, with the backflow absorption liquid of deethanizing cat head liquefaction of gases as light ends tower, the minimum temperature of control device is higher than CO
2Freezing temperature; Ethane and acid gas confused to be recycled in the stratum go
The use properties of accompanying drawing illustrated embodiment, result of use are good.
Claims (2)
1, a kind of carbon dioxide content is characterized in that less than 10% deep cooling process for separating natural gas technical process is that the above component of carbonic acid gas, hydrogen sulfide, ethane and propane is all isolated through the Sweet natural gas cryogenic unit from unstripped gas.
2, carbon dioxide content according to claim 1 is less than 10% deep cooling process for separating natural gas, it is characterized in that: utilize the variation of demethanizing tower or deethanizing column top gaseous component, with the backflow absorption liquid of deethanizing cat head liquefaction of gases as light ends tower, the control device minimum temperature is higher than CO
2Freezing temperature; Ethane and acid gas confused be recycled into the stratum.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN 01134260 CN1342742A (en) | 2001-10-30 | 2001-10-30 | Deep cooling process for separating natural gas with CO2 content less than 10% |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN 01134260 CN1342742A (en) | 2001-10-30 | 2001-10-30 | Deep cooling process for separating natural gas with CO2 content less than 10% |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN1342742A true CN1342742A (en) | 2002-04-03 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN 01134260 Pending CN1342742A (en) | 2001-10-30 | 2001-10-30 | Deep cooling process for separating natural gas with CO2 content less than 10% |
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|---|---|
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Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101652617A (en) * | 2007-02-12 | 2010-02-17 | 唐纳德·里欧·斯廷森 | Natural gas treatment system |
| CN101707919B (en) * | 2007-06-15 | 2012-02-01 | 英国石油化学品有限公司 | A method for the online analysis of a vapour phase process stream |
| CN101703865B (en) * | 2009-04-27 | 2012-06-13 | 南通泰禾化工有限公司 | Method for treating fetid exhaust gas in production process of sulfo-amino ester |
| CN103590795A (en) * | 2013-10-16 | 2014-02-19 | 大连理工大学 | Integrated method of re-injecting CO2 waste gas to enhance natural gas recovery and CO2 geological storage |
| CN105716372A (en) * | 2016-03-01 | 2016-06-29 | 神华集团有限责任公司 | Method for decarbonizing and desulphurizing crude gas |
-
2001
- 2001-10-30 CN CN 01134260 patent/CN1342742A/en active Pending
Cited By (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101652617A (en) * | 2007-02-12 | 2010-02-17 | 唐纳德·里欧·斯廷森 | Natural gas treatment system |
| CN101652617B (en) * | 2007-02-12 | 2013-07-03 | 唐纳德·里欧·斯廷森 | Natural Gas Processing System |
| US8529666B2 (en) | 2007-02-12 | 2013-09-10 | Donald Leo Stinson | System for dehydrating and cooling a produced gas to remove natural gas liquids and waste liquids |
| US8800671B2 (en) | 2007-02-12 | 2014-08-12 | Donald Leo Stinson | System for separating a waste material from a produced gas and injecting the waste material into a well |
| CN101707919B (en) * | 2007-06-15 | 2012-02-01 | 英国石油化学品有限公司 | A method for the online analysis of a vapour phase process stream |
| CN101703865B (en) * | 2009-04-27 | 2012-06-13 | 南通泰禾化工有限公司 | Method for treating fetid exhaust gas in production process of sulfo-amino ester |
| CN103590795A (en) * | 2013-10-16 | 2014-02-19 | 大连理工大学 | Integrated method of re-injecting CO2 waste gas to enhance natural gas recovery and CO2 geological storage |
| CN105716372A (en) * | 2016-03-01 | 2016-06-29 | 神华集团有限责任公司 | Method for decarbonizing and desulphurizing crude gas |
| CN105716372B (en) * | 2016-03-01 | 2018-05-25 | 神华集团有限责任公司 | The method of raw gas decarbonization, desulfuration |
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