CN106987241A - A kind of low dosage Compositional type hydrate inhibitor for natural gas - Google Patents
A kind of low dosage Compositional type hydrate inhibitor for natural gas Download PDFInfo
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- CN106987241A CN106987241A CN201710226029.5A CN201710226029A CN106987241A CN 106987241 A CN106987241 A CN 106987241A CN 201710226029 A CN201710226029 A CN 201710226029A CN 106987241 A CN106987241 A CN 106987241A
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- inhibitor
- natural gas
- low dosage
- hydrate inhibitor
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- 239000003112 inhibitor Substances 0.000 title claims abstract description 66
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 41
- 239000003345 natural gas Substances 0.000 title claims abstract description 20
- 239000013530 defoamer Substances 0.000 claims abstract description 8
- 239000002904 solvent Substances 0.000 claims abstract description 5
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 30
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 30
- 235000002639 sodium chloride Nutrition 0.000 claims description 17
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 15
- 239000011780 sodium chloride Substances 0.000 claims description 15
- 229920000570 polyether Polymers 0.000 claims description 12
- POAOYUHQDCAZBD-UHFFFAOYSA-N 2-butoxyethanol Chemical compound CCCCOCCO POAOYUHQDCAZBD-UHFFFAOYSA-N 0.000 claims description 11
- 239000003795 chemical substances by application Substances 0.000 claims description 11
- MTHSVFCYNBDYFN-UHFFFAOYSA-N diethylene glycol Chemical compound OCCOCCO MTHSVFCYNBDYFN-UHFFFAOYSA-N 0.000 claims description 11
- 239000004721 Polyphenylene oxide Substances 0.000 claims description 10
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 10
- WFIZEGIEIOHZCP-UHFFFAOYSA-M potassium formate Chemical compound [K+].[O-]C=O WFIZEGIEIOHZCP-UHFFFAOYSA-M 0.000 claims description 7
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 6
- -1 alkyl glucosides Chemical class 0.000 claims description 6
- 229920000036 polyvinylpyrrolidone Polymers 0.000 claims description 6
- 239000002202 Polyethylene glycol Substances 0.000 claims description 5
- 125000000217 alkyl group Chemical group 0.000 claims description 5
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 4
- 229920001223 polyethylene glycol Polymers 0.000 claims description 3
- CBOCVOKPQGJKKJ-UHFFFAOYSA-L Calcium formate Chemical compound [Ca+2].[O-]C=O.[O-]C=O CBOCVOKPQGJKKJ-UHFFFAOYSA-L 0.000 claims description 2
- 239000004280 Sodium formate Substances 0.000 claims description 2
- CDQSJQSWAWPGKG-UHFFFAOYSA-N butane-1,1-diol Chemical compound CCCC(O)O CDQSJQSWAWPGKG-UHFFFAOYSA-N 0.000 claims description 2
- 229940044172 calcium formate Drugs 0.000 claims description 2
- 235000019255 calcium formate Nutrition 0.000 claims description 2
- 239000004281 calcium formate Substances 0.000 claims description 2
- 229920001577 copolymer Polymers 0.000 claims description 2
- 229920002401 polyacrylamide Polymers 0.000 claims description 2
- 229920001451 polypropylene glycol Polymers 0.000 claims description 2
- 239000001103 potassium chloride Substances 0.000 claims description 2
- 235000011164 potassium chloride Nutrition 0.000 claims description 2
- 229960002816 potassium chloride Drugs 0.000 claims description 2
- 229960002668 sodium chloride Drugs 0.000 claims description 2
- HLBBKKJFGFRGMU-UHFFFAOYSA-M sodium formate Chemical compound [Na+].[O-]C=O HLBBKKJFGFRGMU-UHFFFAOYSA-M 0.000 claims description 2
- 235000019254 sodium formate Nutrition 0.000 claims description 2
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims 2
- 229930182478 glucoside Natural products 0.000 claims 2
- MXRGSJAOLKBZLU-UHFFFAOYSA-N 3-ethenylazepan-2-one Chemical compound C=CC1CCCCNC1=O MXRGSJAOLKBZLU-UHFFFAOYSA-N 0.000 claims 1
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims 1
- 239000001110 calcium chloride Substances 0.000 claims 1
- 229910001628 calcium chloride Inorganic materials 0.000 claims 1
- 229960002713 calcium chloride Drugs 0.000 claims 1
- 235000011148 calcium chloride Nutrition 0.000 claims 1
- 150000008131 glucosides Chemical class 0.000 claims 1
- 229920001519 homopolymer Polymers 0.000 claims 1
- 239000007789 gas Substances 0.000 abstract description 21
- 150000004677 hydrates Chemical class 0.000 abstract description 11
- 230000001629 suppression Effects 0.000 abstract description 6
- 230000002265 prevention Effects 0.000 abstract description 5
- 230000007613 environmental effect Effects 0.000 abstract description 4
- 238000012360 testing method Methods 0.000 description 26
- 239000007864 aqueous solution Substances 0.000 description 20
- 239000000243 solution Substances 0.000 description 17
- 230000015572 biosynthetic process Effects 0.000 description 9
- 239000002518 antifoaming agent Substances 0.000 description 7
- 230000000052 comparative effect Effects 0.000 description 6
- WHNWPMSKXPGLAX-UHFFFAOYSA-N N-Vinyl-2-pyrrolidone Chemical compound C=CN1CCCC1=O WHNWPMSKXPGLAX-UHFFFAOYSA-N 0.000 description 5
- 235000013855 polyvinylpyrrolidone Nutrition 0.000 description 5
- JBKVHLHDHHXQEQ-UHFFFAOYSA-N Caprolactam Natural products O=C1CCCCCN1 JBKVHLHDHHXQEQ-UHFFFAOYSA-N 0.000 description 4
- 150000001875 compounds Chemical class 0.000 description 4
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 description 4
- 238000002360 preparation method Methods 0.000 description 4
- 238000004781 supercooling Methods 0.000 description 4
- 238000003786 synthesis reaction Methods 0.000 description 4
- 230000015556 catabolic process Effects 0.000 description 3
- 238000006731 degradation reaction Methods 0.000 description 3
- 238000005553 drilling Methods 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- WGCNASOHLSPBMP-UHFFFAOYSA-N hydroxyacetaldehyde Natural products OCC=O WGCNASOHLSPBMP-UHFFFAOYSA-N 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 238000011056 performance test Methods 0.000 description 3
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 2
- 239000013000 chemical inhibitor Substances 0.000 description 2
- 229910052739 hydrogen Inorganic materials 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000008239 natural water Substances 0.000 description 2
- 238000006116 polymerization reaction Methods 0.000 description 2
- 229910052717 sulfur Inorganic materials 0.000 description 2
- 239000011593 sulfur Substances 0.000 description 2
- 239000004094 surface-active agent Substances 0.000 description 2
- DZSVIVLGBJKQAP-UHFFFAOYSA-N 1-(2-methyl-5-propan-2-ylcyclohex-2-en-1-yl)propan-1-one Chemical class CCC(=O)C1CC(C(C)C)CC=C1C DZSVIVLGBJKQAP-UHFFFAOYSA-N 0.000 description 1
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- ZAMOUSCENKQFHK-UHFFFAOYSA-N Chlorine atom Chemical compound [Cl] ZAMOUSCENKQFHK-UHFFFAOYSA-N 0.000 description 1
- 208000005189 Embolism Diseases 0.000 description 1
- 229920003171 Poly (ethylene oxide) Polymers 0.000 description 1
- 208000027418 Wounds and injury Diseases 0.000 description 1
- 230000002421 anti-septic effect Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 239000000460 chlorine Substances 0.000 description 1
- 229910052801 chlorine Inorganic materials 0.000 description 1
- 229940060038 chlorine Drugs 0.000 description 1
- 235000017168 chlorine Nutrition 0.000 description 1
- 238000004581 coalescence Methods 0.000 description 1
- 238000013329 compounding Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 239000002178 crystalline material Substances 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000003912 environmental pollution Methods 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 229930182470 glycoside Natural products 0.000 description 1
- 150000002338 glycosides Chemical class 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 230000005764 inhibitory process Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 208000014674 injury Diseases 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000008204 material by function Substances 0.000 description 1
- 244000005700 microbiome Species 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 230000000116 mitigating effect Effects 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 230000006911 nucleation Effects 0.000 description 1
- 238000010899 nucleation Methods 0.000 description 1
- 239000003960 organic solvent Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000036314 physical performance Effects 0.000 description 1
- 229920000768 polyamine Polymers 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000002861 polymer material Substances 0.000 description 1
- 229920001296 polysiloxane Polymers 0.000 description 1
- 239000001267 polyvinylpyrrolidone Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 241000894007 species Species 0.000 description 1
- 238000003756 stirring Methods 0.000 description 1
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 description 1
- 229920001897 terpolymer Polymers 0.000 description 1
- 230000001988 toxicity Effects 0.000 description 1
- 231100000419 toxicity Toxicity 0.000 description 1
- ZIBGPFATKBEMQZ-UHFFFAOYSA-N triethylene glycol Chemical compound OCCOCCOCCO ZIBGPFATKBEMQZ-UHFFFAOYSA-N 0.000 description 1
- 229920002554 vinyl polymer Polymers 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/524—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/22—Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/32—Anticorrosion additives
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Compositions Of Macromolecular Compounds (AREA)
- Agricultural Chemicals And Associated Chemicals (AREA)
Abstract
The present invention relates to a kind of low dosage Compositional type hydrate inhibitor for natural gas.When mainly solving prevention and control gas hydrates present in prior art, thermodynamic inhibitor consumption is big, accumulating running cost is high and the problem of the poor feature of environmental protection.The inhibitor of the present invention, includes by weight percentage：5~40% APGs, 0~10% synergist, 48~95% solvents, the technical scheme of 0~2% defoamer preferably solves above mentioned problem.The inhibitor of the present invention has the features such as low adding amount, good suppression gas hydrates performance, good economy performance, environmental protection, available for gas hydrates prevention and control field.
Description
Technical field
The present invention relates to a kind of low dosage Compositional type hydrate inhibitor for natural gas.
Background technology
Gas hydrates are the crystalline materials for the species ice-like that natural gas and water are formed under low temperature and condition of high voltage,
It is incendivity that outward appearance meets fire as ice, also referred to as " combustible ice ", " solid gas " or " gas ice ".Gas hydrates are in exploitation day
Formed in the pipeline of right gas, line clogging can be caused, reduce the output quantity of natural gas, increase the pressure difference of pipeline, damaged pipe fitting and set
It is standby, cause serious pipeline accident, or even cause gas well to stop production.Gas hydrates in pipeline are prevented and treated in gas industry at present
The most effective and conventional method of embolism is injection chemical inhibitor, and it can suppress the formation of gas hydrates, can also
Dissolve established gas hydrates.Current domestic each Gas Fields are mainly hydrated using methanol as chemical inhibitor come prevention and control
The formation of thing, methanol is used as traditional thermodynamics hydrate inhibitor, although can effectively suppress the formation of hydrate, but there is also
Methanol dosing is big, volatile, has stronger toxicity, to environment and artificial into certain injury, and is mixed with the production of methanol
Sewage must be recycled, and accumulating and running cost are higher.Methanol has no longer met that gas field is safe and environment-friendly, inexpensive open
The need for hair.The major research institutions of Abroad in Recent Years, such as BASF BASF, BP BP, shell SHELL, Mobil Mobile
Develop the kinetic inhibitor using high-molecular compound as active component of low dosage in succession Deng company（KHI）, polymerization inhibitor
（AA）Deng, but can not still be used when using at the scene in the presence of such as polymer dynamics inhibitor under high supercooling degree, exist turbid
Point, synthesis cost is higher, the low problem of degradation rate；Although the polymerization inhibitor based on surfactant can bear higher supercooling
Degree, but used there is also needs in the oil-water coexistence pipeline of by-product condensate, cost is high, the problem of degradation rate is low so that this
Only a small amount of condition compares the land gas well of mitigation and applied abroad for class inhibitor.Also there is development correlative study the country.
CN101629071B discloses a kind of efficient combined inhibitor for suppressing gas hydrate generation.The inhibitor
It is according to quality proportioning 1 by polyvinylpyrrolidone, three kinds of materials of polyetheramine and butyl glycol ether:1:1 formulated in combination is formed.Suppression
Total mass concentration when preparation is used is 0.2-2%.Inhibitor is applied in oilfield drilling mining system, and usage amount is small, efficiently
Advantage.
CN102504786B discloses a kind of sulfur-containing natural gas hydrate inhibitor, by weight 100% meter：Dynamics is hydrated
Thing inhibitor 10-30%, surfactant 10-30%, defoamer 2-5%, corrosion inhibiter 2-5% and organic solvent 50-70%, dynamics
Hydrate inhibitor is N- caprolactam and 2- acrylamido -2- methyl-prop of the weight average molecular weight in 5000-20000
N vinyl pyrrolidone, N- caprolactam of the bipolymer or weight average molecular weight of sulfonate in 6000-30000
With the terpolymer of 2- acrylamide-2-methylpro panesulfonic acid salt；The hydrate inhibitor is applied to prevent high temperature, high salt
Gas hydrate synthesis in sulfur-containing gas gathering system, prevents gas hydrate synthesis from blocking, and has to gathering line and ground installation
Antiseptic effect.
CN104293326A discloses a kind of petroleum drilling fluid hydrate inhibitor for natural gas, is mainly used in wellbore fluid
System.The hydrate inhibitor for natural gas of the invention is a kind of kinetic inhibitor, thermodynamic inhibitor, polyamine class and defoamer
Mixture.The inhibitor is 5-35MPa using pressure, and temperature in use is at -10~30 DEG C.The inhibitor consumption is few, with relatively low dense
Degree is mixed into drilling fluid, and reduction gas hydrates nucleation, growth, the speed of coalescence, environmental pollution are small.
In addition to above-mentioned patent, there are other functional materials to be developed to as hydrate inhibitor, but all there is conjunction
Into high polymer material cost is high, difficult degradation the problems such as, being this Patent exploitation of the present invention, a kind of adding amount is low, suppress natural gas
It is hydrated good physical performance, good economy performance, degradable environmentally friendly hydrate inhibitor.
The content of the invention
When the technical problems to be solved by the invention are prevention and control gas hydrates present in prior art, thermodynamics suppression
Preparation consumption is big, accumulating running cost is high and the problem of the poor feature of environmental protection.
In order to solve the above technical problems, the technical solution adopted by the present invention is as follows：A kind of low dosage Compositional type gas water
Compound inhibitors, it is characterised in that inhibitor includes by weight percentage：5~40% APGs, 0~10% synergist,
48~95% solvents, 0~2% defoamer.
In above-mentioned technical proposal, it is C that described APG, which is selected from alkyl number,4~C16Straight chain type or branch chain type alkyl sugar
At least one of glycosides.
In above-mentioned technical proposal, described synergist is selected from sodium formate, potassium formate, calcium formate, sodium chloride, potassium chloride, chlorine
Change calcium, polyetheramine, PEO, polyethylene glycol, polypropylene glycol, polyacrylamide, PVP, polyvinyl
One or more in caprolactam.
In above-mentioned technical proposal, described solvent is selected from water, methanol, ethanol, ethylene glycol, diethylene glycol, triethylene glycol, third
At least one of glycol, butanediol, butyl glycol ether, ethylene glycol monobutyl ether.
In above-mentioned technical proposal, described defoamer may be selected from one kind in copolyether, polyether siloxane copolymer
Or it is a variety of.
The hydrate inhibitor of the present invention is with surface-active height, ecological security and good biocompatibility, microorganism drop
The excellent APG of solution property is primary functional components, the efficient hydrate inhibitor through compounding.Because APG is
Amphi-pathic compound with hydrophilic group and lipophilic group, hydrophilic group can reduce the activity of water with hydrone formation hydrogen bond, lipophilic group
There is alkyl chain steric hindrance natural gas molecule can be hindered to enter in water cage, reduce the interaction between natural gas and water, from
And reach the purpose for suppressing gas hydrate synthesis.When using inhibitor of the present invention, synergist can be added in inhibitor solution and entered
One step lifts the performance of inhibitor.Because APG can may also function as inhibition in inner-walls of duct formation diaphragm to pipeline
Agent function, further improves the economy of inhibitor.Therefore, inhibitor of the present invention have adding amount it is low, suppress gas water
Compound performance is good, good economy performance, environmental protection the features such as, available for gas hydrates prevention and control field.
Embodiment
Below by embodiment, the present invention is further elaborated, but the implementation of the present invention is not limited to this.
The performance test of the hydrate inhibitor for natural gas of the present invention is carried out in the reaction under high pressure handkerchief kettle independently transformed,
Handkerchief kettle volume 1L, maximum pressure 10MPa, circulation deep cooling bath can make the operating temperature range of handkerchief kettle at -30~25 DEG C, by suppression to be measured
Formulation samples and salt-containing solution（Simulated formation water）It is fitted into after mixing in proportion in handkerchief kettle, being filled with natural gas arrives system pressure
Designated value, the time that record pressure is begun to decline under stirring is as the time for judging hydrate appearance.Test condition：It is real
Test -3 DEG C of pressure 6.5MPa, experimental temperature（18 DEG C of degree of supercooling）, 300 revs/min of speed of agitator, natural gas composition be shown in Table 1.
The natural gas of table 1 is constituted
| Component | CH4 | C2H6 | C3H8 | C4H10 | C5H12 | He | N2 | CO2 | H2S |
| Content % | 94.50 | 0.47 | 0.06 | 0.01 | 0.01 | 0.03 | 0.21 | 4.70 | 0.01 |
【Embodiment 1】
By weight percentage, 30% C12APG, 10% potassium formate, the 59% ethylene glycol monobutyl ether aqueous solution（Concentration 50%）,
1% polyether antifoam agent is configured to hydrate inhibitor A, in the NaCl aqueous solution for adding it to 3.5%, makes inhibitor in solution
In mass percent concentration be 1%.Sample to be tested is added to progress hydrate rejection test in high pressure handkerchief kettle, test
It the results are shown in Table 2.
【Embodiment 2】
By weight percentage, 30% C8APG, 10% potassium formate, the 59% ethylene glycol monobutyl ether aqueous solution（Concentration 50%）, 1%
Polyether antifoam agent is configured to hydrate inhibitor B, in the NaCl aqueous solution for adding it to 3.5%, makes inhibitor in the solution
Mass percent concentration is 1%.Sample to be tested is added to progress hydrate rejection test, test result in high pressure handkerchief kettle
It is shown in Table 2.
【Embodiment 3】
By weight percentage, 30% C12APG, 10% polyetheramine, the 59% ethylene glycol monobutyl ether aqueous solution（Concentration 50%）,
1% polyether antifoam agent is configured to hydrate inhibitor C, in the NaCl aqueous solution for adding it to 3.5%, makes inhibitor in solution
In mass percent concentration be 1%.Sample to be tested is added to progress hydrate rejection test in high pressure handkerchief kettle, test
It the results are shown in Table 2.
【Embodiment 4】
By weight percentage, 30% C12APG, 10% polyethylene glycol, the 59% ethylene glycol monobutyl ether aqueous solution（Concentration
50%）, 1% polyether antifoam agent is configured to hydrate inhibitor D, in the NaCl aqueous solution for adding it to 3.5%, inhibitor is existed
Mass percent concentration in solution is 1%.Sample to be tested is added to progress hydrate rejection test in high pressure handkerchief kettle,
Test result is shown in Table 2.
【Embodiment 5】
By weight percentage, 30% C12APG, 10% PVP, the 59% ethylene glycol monobutyl ether aqueous solution
（Concentration 50%）, 1% polyether antifoam agent is configured to hydrate inhibitor E, in the NaCl aqueous solution for adding it to 3.5%, makes suppression
The mass percent concentration of preparation in the solution is 1%.Sample to be tested is added to progress hydrate rejection in high pressure handkerchief kettle
Test, test result is shown in Table 2.
【Embodiment 6】
By weight percentage, 35% C12APG, the 64% ethylene glycol monobutyl ether aqueous solution（Concentration 50%）, 1% polyethers froth breaking
Agent is configured to hydrate inhibitor F, in the NaCl aqueous solution for adding it to 3.5%, makes the quality percentage of inhibitor in the solution
Specific concentration is 1%.Sample to be tested is added to progress hydrate rejection test in high pressure handkerchief kettle, test result is shown in Table 2.
【Embodiment 7】
By weight percentage, 30% C12APG, 10% potassium formate, 59% methanol aqueous solution（Concentration 50%）, 1% polyethers silicon
Oxygen alkane defoamer is configured to hydrate inhibitor G, in the NaCl aqueous solution for adding it to 3.5%, makes inhibitor in the solution
Mass percent concentration is 1%.Sample to be tested is added to progress hydrate rejection test, test result in high pressure handkerchief kettle
It is shown in Table 2.
【Embodiment 8】
By weight percentage, 35% C12APG, 64% glycol water（Concentration 50%）, the preparation of 1% polyether antifoam agent
Into hydrate inhibitor H, in the NaCl aqueous solution for adding it to 3.5%, make the mass percent concentration of inhibitor in the solution
For 1%.Sample to be tested is added to progress hydrate rejection test in high pressure handkerchief kettle, test result is shown in Table 2.
【Embodiment 9】
By weight percentage, 15% C8APG, 15% C12APG, 10% potassium formate, 59.8% glycol water
（Concentration 50%）, 0.2% polyether silicone defoamer is configured to hydrate inhibitor I, adds it to the 3.5% NaCl aqueous solution
In, it is 1% to make the mass percent concentration of inhibitor in the solution.Sample to be tested is added in high pressure handkerchief kettle and carries out hydrate
Rejection is tested, and test result is shown in Table 2.
【Embodiment 10】
By weight percentage, 10% C4APG, 20% C10APG, 10% potassium formate, 59% ethylene glycol monobutyl ether water
Solution（Concentration 50%）, 1% polyether antifoam agent is configured to hydrate inhibitor J, in the NaCl aqueous solution for adding it to 3.5%,
It is 1% to make the mass percent concentration of inhibitor in the solution.Sample to be tested is added to progress hydrate suppression in high pressure handkerchief kettle
Performance test, test result is shown in Table 2.
【Comparative example 1】
Without inhibitor, is directly added to progress hydrate rejection test in high pressure handkerchief kettle by the 3.5% NaCl aqueous solution,
Test result is shown in Table 2.
【Comparative example 2】
Thermodynamic inhibitor methanol is added in the 3.5% NaCl aqueous solution, makes the mass percent concentration of methanol in the solution
For 15%.Sample to be tested is added to progress hydrate rejection test in high pressure handkerchief kettle, test result is shown in Table 2.
【Comparative example 3】
PVP is added in the 3.5% NaCl aqueous solution, makes the matter of PVP in the solution
It is 1% to measure percent concentration.Sample to be tested is added to progress hydrate rejection test in high pressure handkerchief kettle, test result is shown in
Table 2.
The inhibitor the performance test results of table 2
| Detect sample | Pressure/MPa | Temperature/DEG C | Degree of supercooling/DEG C | Hydrate time of occurrence/min |
| A | 6.5 | -3 | 18 | 183 |
| B | 6.5 | -3 | 18 | 170 |
| C | 6.5 | -3 | 18 | 190 |
| D | 6.5 | -3 | 18 | 172 |
| E | 6.5 | -3 | 18 | 208 |
| F | 6.5 | -3 | 18 | 165 |
| G | 6.5 | -3 | 18 | 173 |
| H | 6.5 | -3 | 18 | 178 |
| I | 6.5 | -3 | 18 | 181 |
| J | 6.5 | -3 | 18 | 169 |
| Comparative example 1 | 6.5 | -3 | 18 | 5 |
| Comparative example 2 | 6.5 | -3 | 18 | 20 |
| Comparative example 3 | 6.5 | -3 | 18 | 45 |
Claims (5)
1. a kind of low dosage Compositional type hydrate inhibitor for natural gas, it is characterised in that inhibitor includes by weight percentage：5
~40% APG, 0~10% synergist, 48~95% solvents, 0~2% defoamer.
2. low dosage Compositional type hydrate inhibitor for natural gas according to claim 1, it is characterised in that described alkyl
It is C that glucosides, which is selected from alkyl number,4~C16Straight chain type or at least one of branch chain type alkyl glucosides.
3. low dosage Compositional type hydrate inhibitor for natural gas according to claim 1, it is characterised in that described synergy
Agent may be selected from sodium formate, potassium formate, calcium formate, sodium chloride, potassium chloride, calcium chloride, polyetheramine, PEO, polyethylene glycol,
One or more in polypropylene glycol, polyacrylamide, PVP, Vinylcaprolactam homopolymer.
4. low dosage Compositional type hydrate inhibitor for natural gas according to claim 1, it is characterised in that described solvent
Selected from water, methanol, ethanol, ethylene glycol, diethylene glycol, triethylene glycol, propane diols, butanediol, butyl glycol ether, ethylene glycol only son
At least one of ether.
5. low dosage Compositional type hydrate inhibitor for natural gas according to claim 1, it is characterised in that described froth breaking
Agent may be selected from the one or more in copolyether, polyether siloxane copolymer.
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Cited By (7)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN107795848A (en) * | 2017-09-30 | 2018-03-13 | 天津大学 | A kind of Compositional type hydrate inhibitor for natural gas of the amphipathic copolymer containing POSS and preparation method thereof |
| CN111996051A (en) * | 2020-09-14 | 2020-11-27 | 扬州大学 | Hydrating agent for preparing natural gas hydrate |
| CN112592704A (en) * | 2020-12-30 | 2021-04-02 | 天津新翔油气技术有限公司 | High-temperature-resistant hydrate inhibitor and preparation method thereof |
| CN113817443A (en) * | 2020-06-18 | 2021-12-21 | 中国石油化工股份有限公司 | Hydrate decomposition inhibiting composition, coupling enhanced solid hydrate and method for enhancing storage and transportation stability of solid hydrate |
| CN114058344A (en) * | 2020-08-10 | 2022-02-18 | 中国石油天然气股份有限公司 | Multi-effect additive for natural gas exploitation and preparation method and application thereof |
| CN114539994A (en) * | 2022-04-24 | 2022-05-27 | 山东维斯特尔石油科技有限公司 | Reservoir drilling fluid system and preparation method thereof |
| WO2023122947A1 (en) * | 2021-12-28 | 2023-07-06 | 大连理工大学 | Environmentally-friendly natural gas hydrate inhibitor and application |
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Cited By (11)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN107795848A (en) * | 2017-09-30 | 2018-03-13 | 天津大学 | A kind of Compositional type hydrate inhibitor for natural gas of the amphipathic copolymer containing POSS and preparation method thereof |
| CN107795848B (en) * | 2017-09-30 | 2019-06-11 | 天津大学 | A kind of Compositional type hydrate inhibitor for natural gas of the amphipathic copolymer containing POSS and preparation method thereof |
| CN113817443A (en) * | 2020-06-18 | 2021-12-21 | 中国石油化工股份有限公司 | Hydrate decomposition inhibiting composition, coupling enhanced solid hydrate and method for enhancing storage and transportation stability of solid hydrate |
| CN113817443B (en) * | 2020-06-18 | 2022-08-30 | 中国石油化工股份有限公司 | Hydrate decomposition inhibiting composition, coupling enhanced solid hydrate and method for enhancing storage and transportation stability of solid hydrate |
| CN114058344A (en) * | 2020-08-10 | 2022-02-18 | 中国石油天然气股份有限公司 | Multi-effect additive for natural gas exploitation and preparation method and application thereof |
| CN111996051A (en) * | 2020-09-14 | 2020-11-27 | 扬州大学 | Hydrating agent for preparing natural gas hydrate |
| CN112592704A (en) * | 2020-12-30 | 2021-04-02 | 天津新翔油气技术有限公司 | High-temperature-resistant hydrate inhibitor and preparation method thereof |
| CN112592704B (en) * | 2020-12-30 | 2022-09-20 | 天津新翔油气技术有限公司 | High-temperature-resistant hydrate inhibitor and preparation method thereof |
| WO2023122947A1 (en) * | 2021-12-28 | 2023-07-06 | 大连理工大学 | Environmentally-friendly natural gas hydrate inhibitor and application |
| CN114539994A (en) * | 2022-04-24 | 2022-05-27 | 山东维斯特尔石油科技有限公司 | Reservoir drilling fluid system and preparation method thereof |
| CN114539994B (en) * | 2022-04-24 | 2022-07-15 | 山东维斯特尔石油科技有限公司 | Reservoir drilling fluid system and preparation method thereof |
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