WO2015065239A1 - Production multi-tonnage pour la transformation de gaz naturels de gisements divers - Google Patents

Production multi-tonnage pour la transformation de gaz naturels de gisements divers Download PDF

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Publication number
WO2015065239A1
WO2015065239A1 PCT/RU2014/000739 RU2014000739W WO2015065239A1 WO 2015065239 A1 WO2015065239 A1 WO 2015065239A1 RU 2014000739 W RU2014000739 W RU 2014000739W WO 2015065239 A1 WO2015065239 A1 WO 2015065239A1
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gas
gases
production
unit
carbon dioxide
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PCT/RU2014/000739
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English (en)
Russian (ru)
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Игорь Анатольевич МНУШКИН
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Игорь Анатольевич МНУШКИН
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Publication of WO2015065239A1 publication Critical patent/WO2015065239A1/fr

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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • 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
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • 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
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants
    • C10L3/102—Removal of contaminants of acid contaminants
    • C10L3/103—Sulfur containing contaminants
    • 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
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants
    • C10L3/102—Removal of contaminants of acid contaminants
    • C10L3/104—Carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/10—Single element gases other than halogens
    • B01D2257/11—Noble gases
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/30—Sulfur compounds
    • B01D2257/304—Hydrogen sulfide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/50—Carbon oxides
    • B01D2257/504—Carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/70—Organic compounds not provided for in groups B01D2257/00 - B01D2257/602
    • B01D2257/702—Hydrocarbons
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/80—Water

Definitions

  • Multi-tonnage production for the processing of natural gases of various fields providing gas processing in the gas producing region, which can be used in the gas industry in the conditions of its intensive development.
  • Natural gas processing plants are large-capacity industrial enterprises that process up to several billion nm / year of raw gas (several million tons / year).
  • natural gas production volumes increase sharply precisely in those regions where there are no additional technical and human resources. So, for example, in East Siberia and the Far East back in 2010, only 33 billion nm 3 / year of natural gas was produced, of which only 65% was processed, and the remaining 35% was pumped back into the reservoir or flared, but long-term development plans of these regions, the production of natural gas in them by 2030 should be brought up to 200 billion nm 3 / year.
  • Such gas processing plants with a capacity of 20 to 70 billion nm 3 / year for gas to be processed should be attributed to multi-ton production, which can serve several natural gas fields simultaneously.
  • multi-ton production which can serve several natural gas fields simultaneously.
  • Kovyktinsky 40 billion nm 3 / year
  • Chikansky and Angaro-Lensky (18 billion nm 3 / year).
  • Natural gas consisting mainly of methane, contains a number of impurities, in particular, water, nitrogen, hydrogen sulfide, carbon dioxide, helium, mercaptans, light hydrocarbons (ethane, propane, butane), which are harmful impurities that impair to some extent, the quality of fuel gas, and vice versa, valuable components that are raw materials of the gas chemical industry (production of methanol, elemental sulfur, sulfides, unsaturated hydrocarbons, etc.). Moreover, any impurities to methane in natural gas reduce the calorific value of natural gas as a fuel.
  • Natural gas of various deposits differs significantly in the content of impurities and in their set, since the classification of natural gases in the content of helium in them includes rich natural gases (more than 0.5% helium), ordinary (0.1 - ⁇ - 0.5%) ) and poor (less than 0.1%).
  • natural gas from the Kovykta field contains up to 1% vol. nitrogen and helium, which makes it appropriate to release helium (Pat. 2478569 RF.
  • the reserves of helium in natural gases Siberia and the Far East make up 85% of the country's reserves (A.E. Kantorovich, A.G. Korzhubaev, L.V. Eder (Institute of Oil and Gas Geology SB RAS), article at www.geoinform.ru).
  • Closest to the claimed invention is a natural gas processing plant, including process units for extracting water, carbon dioxide, hydrogen sulfide and hydrocarbons C 2 and above, helium from gases, one example of which is production at the Orenburg Gas Processing and Helium Plants, whose raw materials are natural gases of two oil and gas condensate fields (Orenburg, hereinafter referred to as ONGKM, and Karachaganak, hereinafter referred to as ONGKM), significantly azlichayuschiesya in its composition.
  • ONGKM Orenburg Gas Processing and Helium Plants
  • the productivity of raw materials processed is about 27 billion m 3 / year, of which 18 billion m 3 / year of helium-containing gas ONGKM and 9 billion m 3 / year of gas KNGKM in which there is no helium, according to these signs this production refers to multi-tonnage .
  • both types of natural gas differ significantly in the content of hydrogen sulfide and carbon dioxide.
  • the production flow chart includes sequentially amine cleaning units for the gas mixture of ONGKM and KNGKM from hydrogen sulfide and carbon dioxide, production units elemental sulfur in the Klaus process from hydrogen sulfide extracted from gases, and obtaining elemental sulfur from it, separating the deeply purified gas from impurities into parts, one of which, after glycol drying, is additionally dried by gas on adsorption drying gas blocks and fed to cryogenic separation blocks to obtain as final products of methane, ethane, hydrocarbon fractions C3 and higher and helium.
  • Another part of the gas is additionally processed on the blocks of low-temperature oil absorption to obtain dried fuel gas and the fraction of C3 and higher purified from hydrogen sulfide and mercaptans. Simultaneously with gas in production, stabilized commodity condensate, absorbent for oil absorption and natural odorant are obtained from unstable condensate. (SI. Ivanov, “Development of the Orenburg Oil and Gas Condensate Field (ONGKM).” Environmental Protection in the Oil and Gas Complex, 2006, 7, p. 3-9).
  • the task was to develop a highly efficient multi-tonnage production with an expanded assortment of manufactured commercial products in the processing of natural gases of several fields with different compositions.
  • the problem is solved due to the fact that in multi-tonnage production for the processing of natural gases of various fields, including technological units for the extraction of water, carbon dioxide, hydrogen sulfide, hydrocarbons C 2 and above, helium, natural gases significantly differing in the content of impurities, separately processed according to optimal technological schemes with the maximum set of marketable products.
  • Such multi-tonnage natural gas processing plants cannot provide a technological process in a single technological line of series-connected technological units or plants, since there are no mass transfer apparatuses capable of passing millions of nm 3 / h of processed gas due to its gigantic dimensions and disturbance of the hydrodynamic situation in the apparatus.
  • mass transfer apparatuses capable of passing millions of nm 3 / h of processed gas due to its gigantic dimensions and disturbance of the hydrodynamic situation in the apparatus.
  • absorption column capacity 3.6 million nm 3 / h
  • its diameter should be more than 20 m, so large gas processing plants usually have several similar technological processes. threads operating in a single mode for devices of the same type (temperature, pressure, absorbent consumption, etc.).
  • the main features that make it possible to consider natural gases as different are the concentrations of carbon dioxide and hydrogen sulfide in gases, their ratio, as well as the content of helium and hydrocarbons C 2 and higher, since these impurities reduce the calorific value of fuel gas as a target product of processing to 500 kJ / kg for every percent of the impurity.
  • the calorific value of natural gas and, accordingly, commercial purified gas from acidic impurities is influenced by the presence of nitrogen, however, its removal is not the subject of this invention, therefore, the main emphasis on the calorific value of the starting natural gas in this invention is made on the presence of carbon dioxide and hydrogen sulfide.
  • natural gas containing carbon dioxide more than hydrogen sulfide and having its high content be considered as low-calorie natural gas
  • natural gas containing carbon dioxide less than hydrogen sulfide, with a low carbon dioxide content be considered as high-calorie natural gas, which allows to form optimal technological schemes for each type of natural gas.
  • glycol dehydration condensate containing mercaptans which can either be fed directly to odorant or unstable oil and (or) unstable gas condensate, and remove the weathering gases of glycol from hydrogen sulfide and mercaptans using triazine or another substance that chemically binds these components into products that utilize are added to the well, or mixed with unstable oil and (or) unstable gas condensate.
  • the carbon dioxide obtained at the deep amine purification unit of low-calorie natural gas 51 during regeneration of the amine absorbent is sent to the purification unit 59, after which the carbon dioxide is either sent to the atmosphere or into the well for disposal, or it is pumped into fuel gas and other products of gas processing and unstable condensate, either commercial products (dry ice) are produced from it, or they are used as raw materials of a gas chemical enterprise to produce various products.
  • Unstable oil and (or) unstable gas condensate contain ethyl mercaptan and propyl mercaptan to a greater extent than gas raw materials, and to a lesser extent methyl mercaptan, the presence of which in commodity odorants is limited to no more than 4 ppm.
  • the production line for odorants includes a gas separation unit from unstable oil and / or unstable gas condensate and glycol dehydrate condensates 60, an electric desalting unit 61, a stabilization unit 62 to obtain a stabilizer, which is subjected to additional fractionation in a unit 63, which ensures the separation of a hydrocarbon fraction containing mercaptans, and obtaining a marketable product - a stabilizer, part of which is used as absorbent in an absorption extraction plant gas and their compression 64 from the weathering and stabilization gases coming from the gas separation unit 60 and stabilization unit 62, and the hydrocarbon fraction containing mercaptans is sent to the separation unit of mercaptans 65 with their subsequent separation in block 66 into odorants - ethyl mercaptan and propyl mercaptan; the absorbent saturated at the valuable gas extraction unit 60 is sent to the stabilization unit 62, and the stabilization gas compression products are sent for additional purification from hydrogen sulfide to a
  • the production line for dimethyl sulfide or dimethyl disulfide includes a mercaptan drying unit, their fractionation with the release of methyl mercaptan 68, which enters the catalytic or thermal oxidation unit 69 to produce dimethyl sulfide or dimethyl disulfide, and the rest of the fractionation of mercaptans (a mixture of ethyl and propyl mercaptans is sent) 66.
  • the production line for producing a mixture of disulfides from excess mercaptans includes a catalytic or thermal oxidation unit of mercaptans to disulfides 67, which are produced as a commercial product or mixed with stable commercial condensate or oil.
  • FIG. 1 presents a schematic flow chart of the production of the prototype:
  • FIG. 2 is a schematic flow diagram of the processing of natural gases of two different fields, consisting of the following items: 50-56, 61-64 - technological installations; 57-60, 65-69 - technological units; 1-47 - pipelines.
  • Natural gases of two oil and gas condensate fields characterized by the content of hydrogen sulfide and carbon dioxide, are supplied to the unit via pipelines 101 and 102, then they are mixed in a ratio that excludes exceeding the critical content of carbon dioxide in acidic gas, after which the Klaus process becomes ineffective, and through combined pipeline 103 enters installations 210 and 220, where their amine purifications are carried out, and at installation 210 a deep amine purification of carbon dioxide is provided.
  • acid gas is discharged through pipelines 104 and 105, which is mixed and sent through line 106 to sulfur production unit 230, after which elemental sulfur is discharged through line 107, and purified gas from unit 220 is sent through line 108 to install a zeolite gas dehydration and gas purification from mercaptans 240, after which the dried gas is sent through a pipeline 109 to helium blocks 250, from which commodity products: helium, methane, ethane and carbon are respectively discharged through pipelines 110-113 evodorody C 3 and higher.
  • Zeolite regeneration gas from unit 240 is sent via line 114 to amine purification unit 210, from where the purified gas is fed via line 115 to the unit for the production of a mixture of technical propane-butane (SPBT) 260 due to low-temperature oil absorption (NTMA) - a commodity gas separation technology, discharged from the installation through pipelines 116 and 117, and hydrocarbons Cz and above, which are connected via pipeline 118 to pipeline 113 and are removed from the installation.
  • SPBT technical propane-butane
  • NTMA low-temperature oil absorption
  • the disadvantage of the basic technological scheme of the prototype is the maintenance of the proper presence of carbon dioxide in acid gas, which ensures the efficient operation of Klaus, due to the separation of gases after cleaning into two parts, one part of the gas together with the zeolite regeneration gas from the other part of the gas that is supplied to installation of adsorption dehydration 240, through pipeline 115 it enters the SPBT separation unit, from which SPBT with a certain amount of carbon dioxide not absorbed by amine and oil is discharged.
  • Gas I containing carbon dioxide is less than hydrogen sulfide (see Fig. 2) through pipeline 1 enters the installation for deep amine purification of gas I from dioxide carbon and hydrogen sulfide 54, which also receives stabilization gas compression products from the gas absorption and compression unit 64 through pipeline 2.
  • Acid gas I formed during the deep amine purification of gas I at installation 54 is sent through pipeline 3 to the elementary sulfur production unit 58
  • the purified gas I through pipeline 4 is sent to the installation 55, including the zeolite dehydration of gas I and its purification from mercaptans.
  • Dried gas I through pipeline 5 enters the low-temperature fractionation unit of gas I, from which helium, methane, ethane and C3 and higher are discharged, respectively, via pipelines 6–9, while part of the methane is fed through pipeline 10 to zeolite regeneration to installation 55, after which gas regeneration I, which contains hydrogen sulfide and mercaptans, is sent via pipeline 11 to block 57, which consists of purifying regeneration gas I from hydrogen sulfide and mercaptans.
  • Gas II containing carbon dioxide more than hydrogen sulfide, is supplied through pipeline 12 to a deep amine purification unit for gas II from hydrogen sulfide and selective purification from carbon dioxide 50, gas II purified from hydrogen sulfide is fed through pipeline 13 to a deep amine purification from carbon dioxide (installation 51), from where the released carbon dioxide is sent through line 14 to the carbon dioxide purification unit 59 and is discharged from the unit through line 15, and the purified gas II is sent through line 16 to unit 52, including zeolite dehydration of gas II and its purification from mercaptans.
  • the weathering gases of glycol dehydration are neutralized from hydrogen sulfide and mercaptans using a sulfur-binding agent, for example, triazine, since it is not very demanding due to its small the amount of neutralizable impurities, and sent as fuel gas for own needs, including the flue gas afterburner at block 58.
  • a sulfur-binding agent for example, triazine
  • the dried gas II through the pipeline 17 enters the installation of the low-temperature fractionation of gas II 53, from where methane, ethane, and Cz and higher are discharged, respectively, via pipelines 18-20, while part of the methane is supplied pipeline 21 for zeolite regeneration to installation 51, after which regeneration gas II, which contains hydrogen sulfide and mercaptans, is sent through pipeline 22 to block 57, which consists of purification from hydrogen sulfide and mercaptans.
  • the liberated acid gas I and II at block 57 and acid gas II from unit 50 are supplied via pipelines 23 and 24, respectively, to sulfur production unit 58, from where elemental sulfur is discharged through line 25.
  • Mercaptans from block 57 are sent via pipeline 26 to block 68, which consists of drying the mercaptans, fractionating them with the release of methyl mercaptan, which, through pipeline 27, enters the catalytic or thermal oxidation unit 69 to produce dimethyl sulfide or dimethyl disulfide and discharged from the plant through pipeline 28.
  • mercaptans (a mixture of ethyl and propyl mercaptans) from block 68 are sent via line 29 to the odorant fractionation unit 66.
  • Fuel gas I and II from block 57 is discharged from the installation through pipeline 30.
  • the hydrocarbon demercaptanized fraction formed in the mercaptan separation unit 65 is discharged from the unit via pipeline 42 and used as a solvent for washing equipment, while mercaptans are sent through pipeline 43 to the mercaptans separation and odorant generation unit 66, where odorants are withdrawn as commercial products: via pipeline 44 - ethyl mercaptan, and according to pipeline 45 - propyl mercaptan.
  • the mercaptans discharged from block 65 are sent via line 46 to the catalytic or thermal oxidation unit of the mercaptans to obtain disulfides 67 in the mixture, which are connected through line 47 to commodity stable condensate 38 and removed from the unit. You can also display a mixture of disulfides separately as a commercial product (not shown in the figure).
  • Example 1 Considered multi-ton production for the processing of natural gases of various fields according to the prototype on the example of the Orenburg gas processing plant, in which 2.0 million nm 3 / hour of gas of the Orenburg field (gas ONGKM) pre-mixed with 1.0 million nm 3 / hour gas of the Karachaganak field (gas ⁇ ).
  • Table 1 shows the material balance and the range of final products during the processing of a mixture of gases according to the technological scheme shown in FIG. 1, allowing to produce seven types of final products, including two variants of fuel gas.
  • the processing of a mixture of gases leads to the following significant disadvantages:
  • the separation products contain 1811 t / h (a difference of plus 39 t / h), and from the initial 81 t / h of ethane, the separation products contain 142 t / h (a difference of minus 39 t / h); it is obvious that the "excess" of the methane fraction was formed largely due to the lack of clarity in the separation of methane from ethane;
  • Example 2 Considered multi-ton production for the processing of natural gases of various fields according to the claimed invention on the example of design calculations for the reconstruction of the Orenburg gas processing plant with the proposal for separate processing of 2.1 million nm 3 / hour of Orenburg gas and 1.125 million nm 3 / hour of Karachaganak gas, supplemented processing 520 t / h of a mixture of unstable gas condensate and unstable oil ONGKM.
  • Table 2 shows the material balance and the assortment of the final product for “separate” gas processing according to the technological scheme shown in FIG.
  • the claimed invention solves the problem of developing a highly efficient multi-tonnage production with an expanded assortment of manufactured products in the processing of natural gases of several fields with different compositions, while it is possible to optimally operate schemes for the separate processing of natural gases of various compositions using mainly operating equipment, which will allow, in particular, to obtain 99% of helium and to increase the efficiency of the process of obtaining elemental ary sulfur by the Claus to 70% instead of 50%, provided the current prototype production.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Engineering & Computer Science (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Analytical Chemistry (AREA)
  • Gas Separation By Absorption (AREA)
  • Industrial Gases (AREA)

Abstract

L'invention concerne la production multi-tonnage pour la transformation de gaz naturels de gisements divers, comprenant des unités industrielles pour extraire des gaz l'eau, le dioxyde de carbone, le sulfure d'hydrogène, les hydrocarbures С2 et plus, et l'hélium ; les gaz naturels, qui se distinguent essentiellement par leur teneur en impuretés, sont traités séparément dans des circuits industriels optimaux de manière à produire un ensemble maximal de produits commerciaux. En fonction de la concentration de dioxyde de carbone et de sulfure d'hydrogène dans les gaz naturels, on détermine s'ils sont hautement ou faiblement caloriques. L'invention concerne une technique de transformation par séparation des gaz permettant d'élaborer jusqu'à 13 types différents de production.
PCT/RU2014/000739 2013-10-29 2014-10-01 Production multi-tonnage pour la transformation de gaz naturels de gisements divers WO2015065239A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
RU2013148186/05A RU2560406C2 (ru) 2013-10-29 2013-10-29 Способ переработки природных газов
RU2013148186 2013-10-29

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WO2015065239A1 true WO2015065239A1 (fr) 2015-05-07

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RU2685099C1 (ru) * 2018-11-06 2019-04-16 Игорь Анатольевич Мнушкин Производственный кластер
RU2688530C1 (ru) * 2018-12-28 2019-05-21 Игорь Анатольевич Мнушкин Комплекс добычи, сбора, переработки и транспорта природных газов группы месторождений с разным содержанием этана
RU2714123C1 (ru) * 2019-01-10 2020-02-12 Общество с ограниченной ответственностью "Научно-производственное предприятие СИНТЕЗ" Способ получения особо чистых насыщенных углеводородов C3-C4
RU2760488C1 (ru) * 2021-03-10 2021-11-25 Общество с ограниченной ответственностью "Газпром переработка" Способ переработки газа регенерации цеолитов в период остановки на плановый предупредительный ремонт технологических установок аминовой очистки и осушки газа

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Publication number Priority date Publication date Assignee Title
SU1837945A3 (ru) * 1987-10-19 1993-08-30 Vaagner Biro Ag Cпocoб oчиctkи otxoдящиx гaзob ot cepуcoдepжaщиx coeдиhehий
US20050217479A1 (en) * 2004-04-02 2005-10-06 Membrane Technology And Research, Inc. Helium recovery from gas streams
RU2486945C1 (ru) * 2012-05-05 2013-07-10 Евгений Владимирович Левин Способ переработки природного и попутного нефтяного газа

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Publication number Priority date Publication date Assignee Title
SU1837945A3 (ru) * 1987-10-19 1993-08-30 Vaagner Biro Ag Cпocoб oчиctkи otxoдящиx гaзob ot cepуcoдepжaщиx coeдиhehий
US20050217479A1 (en) * 2004-04-02 2005-10-06 Membrane Technology And Research, Inc. Helium recovery from gas streams
RU2486945C1 (ru) * 2012-05-05 2013-07-10 Евгений Владимирович Левин Способ переработки природного и попутного нефтяного газа

Non-Patent Citations (1)

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Title
IVANOV S.I. RAZRABOTKA: "Orenburgskogo neftegazokondensatnogo mestorozhdeniya (ONGKM).", ZASCHITA OKRUZHAJUSCHEI SREDY V NEFTEGAZOVOM KOMPLEKSE, 2006, pages 3 - 31 *

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