CN115872907A - Sulfonate thick oil viscosity reducer and preparation method and application thereof - Google Patents
Sulfonate thick oil viscosity reducer and preparation method and application thereof Download PDFInfo
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- CN115872907A CN115872907A CN202111151123.1A CN202111151123A CN115872907A CN 115872907 A CN115872907 A CN 115872907A CN 202111151123 A CN202111151123 A CN 202111151123A CN 115872907 A CN115872907 A CN 115872907A
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- 239000003638 chemical reducing agent Substances 0.000 title claims abstract description 62
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 title claims abstract description 26
- 238000002360 preparation method Methods 0.000 title claims abstract description 8
- 238000011084 recovery Methods 0.000 claims abstract description 18
- 150000001875 compounds Chemical class 0.000 claims abstract description 15
- 229910001413 alkali metal ion Inorganic materials 0.000 claims abstract description 6
- 229910001420 alkaline earth metal ion Inorganic materials 0.000 claims abstract description 6
- 230000007935 neutral effect Effects 0.000 claims abstract description 4
- 125000001183 hydrocarbyl group Chemical group 0.000 claims abstract 4
- 239000003921 oil Substances 0.000 claims description 55
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 36
- 239000000295 fuel oil Substances 0.000 claims description 27
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 21
- 239000000203 mixture Substances 0.000 claims description 18
- 239000003795 chemical substances by application Substances 0.000 claims description 15
- 238000006277 sulfonation reaction Methods 0.000 claims description 13
- 238000006396 nitration reaction Methods 0.000 claims description 12
- GRYLNZFGIOXLOG-UHFFFAOYSA-N Nitric acid Chemical group O[N+]([O-])=O GRYLNZFGIOXLOG-UHFFFAOYSA-N 0.000 claims description 9
- 238000000034 method Methods 0.000 claims description 9
- ZWWCURLKEXEFQT-UHFFFAOYSA-N dinitrogen pentaoxide Chemical compound [O-][N+](=O)O[N+]([O-])=O ZWWCURLKEXEFQT-UHFFFAOYSA-N 0.000 claims description 8
- 239000002585 base Substances 0.000 claims description 7
- 238000004519 manufacturing process Methods 0.000 claims description 7
- 230000000802 nitrating effect Effects 0.000 claims description 7
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 6
- WFDIJRYMOXRFFG-UHFFFAOYSA-N acetic acid anhydride Natural products CC(=O)OC(C)=O WFDIJRYMOXRFFG-UHFFFAOYSA-N 0.000 claims description 6
- 125000000217 alkyl group Chemical group 0.000 claims description 6
- 238000002156 mixing Methods 0.000 claims description 6
- QAOWNCQODCNURD-UHFFFAOYSA-N sulfuric acid Substances OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 claims description 5
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 4
- 230000033558 biomineral tissue development Effects 0.000 claims description 4
- 229910017604 nitric acid Inorganic materials 0.000 claims description 4
- AKEJUJNQAAGONA-UHFFFAOYSA-N sulfur trioxide Chemical compound O=S(=O)=O AKEJUJNQAAGONA-UHFFFAOYSA-N 0.000 claims description 4
- 239000003513 alkali Substances 0.000 claims description 3
- LMBFAGIMSUYTBN-MPZNNTNKSA-N teixobactin Chemical compound C([C@H](C(=O)N[C@@H]([C@@H](C)CC)C(=O)N[C@@H](CO)C(=O)N[C@H](CCC(N)=O)C(=O)N[C@H]([C@@H](C)CC)C(=O)N[C@@H]([C@@H](C)CC)C(=O)N[C@@H](CO)C(=O)N[C@H]1C(N[C@@H](C)C(=O)N[C@@H](C[C@@H]2NC(=N)NC2)C(=O)N[C@H](C(=O)O[C@H]1C)[C@@H](C)CC)=O)NC)C1=CC=CC=C1 LMBFAGIMSUYTBN-MPZNNTNKSA-N 0.000 claims description 3
- 125000004169 (C1-C6) alkyl group Chemical group 0.000 claims description 2
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 claims description 2
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 claims description 2
- NPYPAHLBTDXSSS-UHFFFAOYSA-N Potassium ion Chemical compound [K+] NPYPAHLBTDXSSS-UHFFFAOYSA-N 0.000 claims description 2
- FKNQFGJONOIPTF-UHFFFAOYSA-N Sodium cation Chemical compound [Na+] FKNQFGJONOIPTF-UHFFFAOYSA-N 0.000 claims description 2
- 229960000583 acetic acid Drugs 0.000 claims description 2
- 150000008044 alkali metal hydroxides Chemical class 0.000 claims description 2
- 229910001860 alkaline earth metal hydroxide Inorganic materials 0.000 claims description 2
- 229910001424 calcium ion Inorganic materials 0.000 claims description 2
- YWEUIGNSBFLMFL-UHFFFAOYSA-N diphosphonate Chemical compound O=P(=O)OP(=O)=O YWEUIGNSBFLMFL-UHFFFAOYSA-N 0.000 claims description 2
- 239000012362 glacial acetic acid Substances 0.000 claims description 2
- 229910001425 magnesium ion Inorganic materials 0.000 claims description 2
- DLYUQMMRRRQYAE-UHFFFAOYSA-N phosphorus pentoxide Inorganic materials O1P(O2)(=O)OP3(=O)OP1(=O)OP2(=O)O3 DLYUQMMRRRQYAE-UHFFFAOYSA-N 0.000 claims description 2
- 229910001414 potassium ion Inorganic materials 0.000 claims description 2
- 229910001415 sodium ion Inorganic materials 0.000 claims description 2
- HIFJUMGIHIZEPX-UHFFFAOYSA-N sulfuric acid;sulfur trioxide Chemical compound O=S(=O)=O.OS(O)(=O)=O HIFJUMGIHIZEPX-UHFFFAOYSA-N 0.000 claims 1
- 230000000694 effects Effects 0.000 abstract description 15
- 238000011156 evaluation Methods 0.000 description 23
- -1 alkylbenzene sulfonate Chemical class 0.000 description 22
- 238000002347 injection Methods 0.000 description 19
- 239000007924 injection Substances 0.000 description 19
- 238000006073 displacement reaction Methods 0.000 description 13
- 238000006243 chemical reaction Methods 0.000 description 10
- 239000011734 sodium Substances 0.000 description 10
- 229910052708 sodium Inorganic materials 0.000 description 10
- 239000010779 crude oil Substances 0.000 description 9
- 239000000047 product Substances 0.000 description 8
- 239000004094 surface-active agent Substances 0.000 description 8
- 239000000243 solution Substances 0.000 description 7
- 230000015572 biosynthetic process Effects 0.000 description 6
- PQNFLJBBNBOBRQ-UHFFFAOYSA-N indane Chemical compound C1=CC=C2CCCC2=C1 PQNFLJBBNBOBRQ-UHFFFAOYSA-N 0.000 description 6
- 238000006467 substitution reaction Methods 0.000 description 6
- 238000003786 synthesis reaction Methods 0.000 description 6
- 239000012528 membrane Substances 0.000 description 5
- 238000003756 stirring Methods 0.000 description 5
- 238000011161 development Methods 0.000 description 4
- 230000018109 developmental process Effects 0.000 description 4
- IAZDPXIOMUYVGZ-UHFFFAOYSA-N Dimethylsulphoxide Chemical compound CS(C)=O IAZDPXIOMUYVGZ-UHFFFAOYSA-N 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 230000001603 reducing effect Effects 0.000 description 3
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 2
- 230000000052 comparative effect Effects 0.000 description 2
- 150000002430 hydrocarbons Chemical group 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000005065 mining Methods 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 125000006702 (C1-C18) alkyl group Chemical group 0.000 description 1
- 125000000923 (C1-C30) alkyl group Chemical group 0.000 description 1
- QMGOXEWNQKNUQO-UHFFFAOYSA-N 1-hexadecyl-2,3-dihydro-1h-indene Chemical compound C1=CC=C2C(CCCCCCCCCCCCCCCC)CCC2=C1 QMGOXEWNQKNUQO-UHFFFAOYSA-N 0.000 description 1
- MKWYUHTUZJDQHB-UHFFFAOYSA-N 1-hexyl-2,3-dihydro-1h-indene Chemical compound C1=CC=C2C(CCCCCC)CCC2=C1 MKWYUHTUZJDQHB-UHFFFAOYSA-N 0.000 description 1
- UHAGUGQCWXOWHP-UHFFFAOYSA-N 1-octyl-2,3-dihydro-1H-indene Chemical compound C(CCCCCCC)C1CCC2=CC=CC=C12 UHAGUGQCWXOWHP-UHFFFAOYSA-N 0.000 description 1
- PEACLFUSUWSZCP-UHFFFAOYSA-N C(CCCCCCCCCCC)C1CCC2=CC=CC=C12 Chemical compound C(CCCCCCCCCCC)C1CCC2=CC=CC=C12 PEACLFUSUWSZCP-UHFFFAOYSA-N 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 150000001298 alcohols Chemical class 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- 150000001768 cations Chemical class 0.000 description 1
- WOWHHFRSBJGXCM-UHFFFAOYSA-M cetyltrimethylammonium chloride Chemical compound [Cl-].CCCCCCCCCCCCCCCC[N+](C)(C)C WOWHHFRSBJGXCM-UHFFFAOYSA-M 0.000 description 1
- 238000001311 chemical methods and process Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- ZBCBWPMODOFKDW-UHFFFAOYSA-N diethanolamine Chemical compound OCCNCCO ZBCBWPMODOFKDW-UHFFFAOYSA-N 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 230000015784 hyperosmotic salinity response Effects 0.000 description 1
- 238000011056 performance test Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 125000001997 phenyl group Chemical group [H]C1=C([H])C([H])=C(*)C([H])=C1[H] 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 230000035484 reaction time Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
Landscapes
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
The invention discloses a sulfonate thick oil viscosity reducer, which comprises at least one of compounds shown as the following formula I, wherein R in the formula I 1 Is C 6 ‑C 30 A hydrocarbon group of R 2 Is H or C 1 ‑C 30 A hydrocarbon group of (a); m is an alkali metal ion or an alkaline earth metal ion, and n is the number of M which can make the compound shown in the formula I be neutral. The invention also discloses a preparation method of the viscosity reducer and application of the viscosity reducer in thick oil exploitation. The sulfonate thick oil viscosity reducer disclosed by the invention has good affinity with thick oil, can effectively reduce the viscosity of the thick oil, has very high interfacial activity, can effectively improve the recovery ratio of the thick oil, and has a good application prospect.
Description
Technical Field
The invention belongs to the field of heavy oil reservoir development, and particularly relates to a sulfonate heavy oil viscosity reducer as well as a preparation method and application thereof.
Background
At present, most of the surfactants for tertiary oil recovery at home and abroad are petroleum sulfonate, heavy alkylbenzene sulfonate and other refinery by-products modified surfactants (CN 1203935A, CN1566258A and CN 1426833A), and the surfactants have the characteristics of wide material sources and low price. However, these surfactants also have a series of problems such as poor salt tolerance, particularly poor divalent cation resistance, and the like, and cannot be applied to high-temperature and high-salinity oil field blocks. Therefore, the development of novel surfactants is of great importance to the tertiary oil recovery industry in our country.
In common reservoirs (first-class reservoirs and second-class reservoirs), surfactants are successfully applied (CN 1458219A), but for heavy oil reservoirs, the surfactants with better effects for the first-class reservoirs and the second-class reservoirs are limited in effect and cannot be used adequately. For heavy oil reservoirs, conventional methods are difficult to recover, and therefore, special technological measures such as thermal oil recovery, chemical oil recovery, biological oil recovery, combination methods and the like are adopted. In recent years, chemical processes have received increasing attention. The main difficulties in heavy oil recovery are high crude oil viscosity, poor crude oil fluidity and high crude oil viscosity, which cause poor sweep efficiency in the displacement process of general displacement fluid (such as hot water). The solution is to reduce the viscosity of the crude oil, reduce the interfacial tension of the crude oil and water, change the wettability of the stratum, and the like.
Therefore, the development of the novel heavy oil viscosity reducer has important significance for heavy oil reservoir exploitation.
Disclosure of Invention
Aiming at the problems in the prior art, the invention aims to provide a novel viscosity reducer which has good affinity with thickened oil, can effectively reduce the viscosity of the thickened oil, has very high interfacial activity, can effectively improve the recovery ratio of the thickened oil and has good application prospect.
One of the technical problems to be solved by the invention is the problem of poor oil displacement effect of a surfactant in a heavy oil reservoir in the prior production technology, and provides a novel sulfonate heavy oil viscosity reducer which can effectively reduce the viscosity of heavy oil and has high interfacial activity, so that the recovery ratio of the heavy oil can be improved. The second technical problem to be solved by the invention is to provide a preparation method of the sulfonate heavy oil viscosity reducer corresponding to the first technical problem. The third technical problem to be solved by the invention is to provide the viscosity reducer with one technical problem or the application of the viscosity reducer prepared by the preparation method with the second technical problem in oil field development, particularly in heavy oil recovery.
To this end, the invention provides a sulfonate thick oil viscosity reducer in a first aspect, which comprises at least one compound shown as the following formula I,
in the formula I, R 1 Is C 6 -C 30 A hydrocarbon group of R 2 Is H or C 1 -C 30 A hydrocarbon group of (a); m is an alkali metal ion or an alkaline earth metal ion, and n is the number of M which enables the compound shown in the formula I to be electrically neutral.
According to some embodiments of the invention, the alkali metal ion is a sodium ion or a potassium ion and the alkaline earth metal ion is a calcium ion or a magnesium ion.
According to the invention, n is the number of M which renders the compound of formula I electrically neutral, for example n =1 when M is an alkali metal ion and n =0.5 when M is an alkaline earth metal ion.
According to some embodiments of the invention, R 1 Is C 6 -C 30 Alkyl group of (1).
According to some embodiments of the invention, R 1 Is C 6 -C 20 Alkyl group of (1).
According to some embodiments of the invention, R 1 Is C 8 -C 16 Alkyl group of (1).
According to some embodiments of the invention, R 2 Is H or C 1 -C 30 Alkyl group of (1).
According to some embodiments of the invention, R 2 Is H or C 1 -C 18 Alkyl group of (1).
According to some embodiments of the invention, R 2 Is H or C 1 -C 10 The alkyl group of (1).
According to some embodiments of the invention, R 2 Is H or C 1 -C 6 Alkyl group of (1).
According to the invention, in formula I, the radical-R 1 and-R 2 The substitution position on the five-membered ring of the indane is not particularly limited, and may be, for example, ortho-substitution or meta-substitution. In some embodiments, the group-R in formula I 1 and-R 2 And the five-membered ring of the indane is substituted by a meta-position.
According to the invention, in formula I, the said-NO 2 and-SO 3 (M) n The substitution position on the benzene ring of indane is not particularly limited, and may be, for example, ortho-, meta-or para-substitution, and preferably meta-substitution.
According to some embodiments of the invention, the viscosity reducer comprises at least one compound represented by formula I-1 below,
in the formula I-1, R 1 ，R 2 M and n have the same meanings as in formula I.
According to some embodiments of the invention, the viscosity reducer comprises at least one compound of formula I-2,
in the formula I-2, R 1 ，R 2 M and n have the same definitions as in formula I.
According to some embodiments of the invention, the viscosity reducer further comprises water having a total mineralization degree of 0 to 80000 mg/L.
According to some embodiments of the invention, the viscosity reducer comprises water with a total mineralization of 100-30000 mg/L.
According to some embodiments of the invention, the water is present in an amount of 90wt% to 99.9wt%, and in some embodiments, 95wt% to 99.9wt%, based on the total mass of the viscosity reducer.
According to the invention, the water with the total mineralization degree of 0-80000mg/L can be at least one of oil field injection water, formation water, seawater, rainwater, river water and the like. For the aspects of construction convenience, water resource saving and the like, the water is more preferably oilfield injection water, for example, the oilfield injection water adopted in the embodiment of the invention is victory oilfield injection water, and the composition of the oilfield injection water is shown in table 1.
According to the invention, the viscosity reducer of the invention can also comprise additives commonly used in the field, for example, in order to increase the oil displacement effect, polyacrylamide, small molecular alcohols, DMSO, diethanolamine, CTAC and the like commonly used in the field can also be included.
In a second aspect of the invention, there is provided a process for preparing a viscosity reducer according to the first aspect of the invention, which comprises the following steps:
a) Mixing the compound shown in the formula II with a nitrating agent to carry out nitration reaction to obtain a nitration product shown in a formula III;
b) Mixing the obtained nitration product with a sulfonating agent to carry out sulfonation reaction to obtain a sulfonated product shown in a formula IV;
c) Mixing the obtained sulfonated product with alkali to obtain a compound shown in a formula I;
in the formulae II, III and IV, R 1 And R 2 Have the same definition as formula I.
According to some embodiments of the present invention, the compound of formula II has a structure as shown in formula II-1 below, the nitrated product of formula III has a structure as shown in formula III-1 below, and the sulfonated product of formula IV has a structure as shown in formula IV-1 below:
in the formulae II-1, III-1, IV-1, R 1 And R 2 Have the same definition as formula I.
According to some embodiments of the invention, the nitrating agent is nitric acid and/or dinitrogen pentoxide or the nitrating agent is a mixture of at least one of nitric acid and dinitrogen pentoxide with at least one of concentrated sulfuric acid, glacial acetic acid, acetic anhydride, phosphorus pentoxide.
According to some embodiments of the invention, the sulfonating agent is selected from at least one of concentrated sulfuric acid, oleum, and sulfur trioxide.
According to some embodiments of the invention, the base is at least one of an alkali metal hydroxide and an alkaline earth metal hydroxide. In some embodiments, the base is sodium hydroxide and/or potassium hydroxide.
According to some embodiments of the invention, in step a), the molar ratio of the compound of formula II to the nitrating agent is (1.
According to some embodiments of the invention, in step b), the molar ratio of the nitrated product to the sulfonating agent is (1.
According to some embodiments of the invention, in step c), the amount of base added is such that the pH of the mixture of sulfonated product and base is adjusted to 7 to 14.
According to some embodiments of the invention, in step a), the temperature of the nitration reaction is between 0 and 80 ℃. In some embodiments, the temperature of the nitration reaction is between 30 ℃ and 70 ℃, such as 30 ℃, 40 ℃, 50 ℃, 60 ℃, 70 ℃ and any value therebetween.
According to some embodiments of the invention, in step a), the time of the nitration reaction is between 1 and 10h. In some embodiments, the time for the nitration reaction is between 1 and 5 hours, such as 1 hour, 2 hours, 3 hours, 4 hours, 5 hours, and any value therebetween.
According to some embodiments of the invention, the temperature of the sulfonation reaction in step b) is 20 to 80 ℃. In some embodiments, the temperature of the sulfonation reaction is 30-60 ℃, such as 30 ℃, 35 ℃, 40 ℃, 45 ℃, 50 ℃, 55 ℃, 60 ℃ and any value therebetween.
According to some embodiments of the invention, in step b), the sulfonation reaction is carried out for a time period of 0.5 to 10 hours. In some embodiments, the sulfonation reaction time is from 0.5 to 5 hours, such as 0.5 hours, 1 hour, 2 hours, 3 hours, 4 hours, 5 hours, and any value therebetween.
In a third aspect, the invention provides a use of the viscosity reducer according to the first aspect of the invention or the viscosity reducer prepared by the preparation method according to the second aspect of the invention in oil field exploitation, in particular thick oil exploitation, such as enhanced thick oil recovery.
According to some embodiments of the invention, in said use, said viscosity reducer is used as an oil displacement agent.
According to some embodiments of the invention, the field production is tertiary oil recovery.
The invention has the beneficial effects that:
the sulfonate heavy oil viscosity reducer disclosed by the invention has good surface and interface activity and good salt resistance, can form low interfacial tension on an oil-water interface, can effectively reduce the viscosity of heavy oil and improve the recovery ratio of the heavy oil, and has wide application prospects and practical significance.
Detailed Description
In order that the present invention may be more readily understood, the following detailed description of the invention is given in conjunction with the examples which are given by way of illustration only and are not to be construed as limiting the scope of the invention. The examples, in which specific conditions are not specified, were carried out according to conventional conditions or conditions recommended by the manufacturer.
The endpoints of the ranges and any values disclosed herein are not limited to the precise range or value, and such ranges or values should be understood to encompass values close to those ranges or values. For numerical ranges, each range between its endpoints and individual point values, and each individual point value can be combined with each other to give one or more new numerical ranges, and such numerical ranges should be construed as specifically disclosed herein.
The relevant data in the examples of the present invention were obtained according to the following test methods:
and (3) evaluating the viscosity reduction effect of the thickened oil: and (3) determining the viscosity reduction rate by adopting a Brookfield viscometer DV-III according to the method of QSH1020 1519-2013 general technical conditions of the thick oil viscosity reducer.
And (3) evaluating interfacial tension: the interfacial tension between the viscosity reducer and the thick oil was measured at 80 ℃ and at 4500 rpm using a TX-500C rotary drop interfacial tensiometer, produced by Texas university, USA.
Oil displacement experiment evaluation: according to the test of the physical simulation oil displacement effect of the complex oil displacement system in the SY/T6424-2000 complex oil displacement system performance test method, the length is 30cm, the diameter is 2.5cm, and the permeability is 1.5m at the temperature of 80 DEG C 2 The core of the oil displacement test is subjected to oil displacement simulation. Firstly, carrying out water flooding by using the prevailing oil field injection water until the water content is 98%, after the water flooding is finished, transferring the prepared viscosity reducer with 0.3pv (core pore volume), then carrying out water flooding until the water content is 98%, and calculating to improve the crude oil recovery ratio.
Example 1
Synthesis of 1.1-hexanyl-4-nitroindan-6-sulfonate
a) Adding 1.0mol of 1-hexylindane into a reactor provided with a condensing device and a stirring device, dropwise adding 2.5mol of fuming nitric acid, controlling the reaction temperature to be 50 ℃, and continuously reacting for 2 hours after dropwise adding is finished to obtain 0.85mol of 1-hexylindane-4-nitroindane;
b) Adding 0.85mol of the hexyl nitroindane synthesized in the step a) into a membrane type sulfonation reaction device, and introducing 1.5mol of SO 3 And controlling the reaction temperature to be 45 ℃, reacting for 30 minutes to obtain 0.81mol 1-hexyl-4-nitroindan-6-sulfonic acid, and adding sodium hydroxide to adjust the pH value to 9 to obtain 1-hexyl-4-nitroindan-6-sodium sulfonate.
2. Evaluation of viscosity reducer Performance
And (3) preparing 0.2wt% of solution of the 1-hexyl-4-nitroindan-6-sodium sulfonate by using the victory oil field mining injection water to obtain the thick oil viscosity reducer for thick oil viscosity reduction effect evaluation and interfacial tension evaluation, wherein the results are shown in the following table 3. Wherein, the compositions of the winning oil field winning injection water are shown in the table 1. The composition of the resulting viscosity reducer is shown in Table 2.
Example 2
Synthesis of 1.1-octyl-4-nitroindan-6-sulfonate
a) Adding 1.0mol of 1-octyl indane into a reactor provided with a condensing device and a stirring device, dropwise adding 2.2mol of fuming nitric acid, controlling the reaction temperature to be 50 ℃, and continuously reacting for 2 hours after dropwise adding is finished to obtain 0.82mol of 1-octyl-4-nitroindane;
b) Adding 0.82mol of 1-octyl-4-nitroindan synthesized in the step a) into a membrane type sulfonation reaction device, and introducing 1.5mol of SO 3 And controlling the reaction temperature to be 45 ℃, reacting for 30 minutes to obtain 0.79mol 1-octyl-4-nitroindane-6-sulfonic acid, and adding sodium hydroxide to adjust the pH value to 9 to obtain 1-octyl-4-nitroindane-6-sodium sulfonate.
2. Evaluation of viscosity reducer Performance
And (3) preparing a 0.5wt% solution of the sodium octyl nitroindane sulfonate by using the victory oil field victory oil production injection water to obtain the thick oil viscosity reducer for thick oil viscosity reduction effect evaluation and interfacial tension evaluation, wherein the results are shown in the following table 3. Wherein, the compositions of the winning oil field winning injection water are shown in the table 1. The composition of the resulting viscosity reducer is shown in Table 2.
Example 3
Synthesis of 1.1-dodecyl-4-nitroindane sulfonate
a) Adding 1.0mol of 1-dodecyl indane into a reactor provided with a condensing device and a stirring device, dropwise adding 1.5mol of fuming nitric acid, controlling the reaction temperature to be 50 ℃, and continuously reacting for 2 hours after dropwise adding is finished to obtain 0.83mol of 1-dodecyl-4-nitroindane;
b) Adding 0.83mol of 1-dodecyl-4-nitroindan synthesized in the step a) into a membrane sulfonation reaction device, and introducing 1.5mol of SO 3 Controlling the reaction temperature to be 45 ℃, reacting for 30 minutes to obtain 0.78mol 1-dodecyl-4-nitroindan-6-sulfonic acid, adding sodium hydroxide to adjust the pH value to 9 to obtain 1-dodecyl-4-nitroindan-6-sulfonic acid sodium salt.
2. Evaluation of viscosity reducer Performance
And (3) preparing 1.0wt% of the 1-dodecyl-4-nitroindan-6-sodium sulfonate solution by using the victory oil field victory oil production injection water to obtain the heavy oil viscosity reducer for the heavy oil viscosity reduction effect evaluation, the interfacial tension evaluation and the oil displacement experiment, wherein the heavy oil viscosity reduction effect evaluation and the interfacial tension evaluation results are shown in the following table 3. Wherein, the compositions of the winning oil field winning injection water are shown in the table 1. The composition of the resulting viscosity reducer is shown in Table 2.
The result shows that the viscosity reducer improves the crude oil recovery by 7.2 percent.
Example 4
Synthesis of 1.1-hexadecyl-4-nitroindane sulfonate
a) Adding 1.0mol of 1-hexadecylindane into a reactor provided with a condensing device and a stirring device, dropwise adding 2.1mol of fuming nitric acid, controlling the reaction temperature to be 50 ℃, and continuously reacting for 2 hours after dropwise adding is finished to obtain 0.81mol of 1-hexadecyl-4-nitroindane;
b) Adding the 0.81mol 1-hexadecyl-4-nitroindane synthesized in the step a) into a membrane type sulfonation reaction device, and introducing 1.5mol of SO 3 And controlling the reaction temperature to be 45 ℃, reacting for 30 minutes to obtain 0.75mol of 1-hexadecyl-4-nitroindan-6-sulfonic acid, and adding sodium hydroxide to adjust the pH value to 9 to obtain the 1-hexadecyl-4-nitroindan-6-sodium sulfonate.
2. Evaluation of viscosity reducer Performance
And (3) preparing 0.5wt% of the solution of the 1-hexadecyl-4-nitroindan-6-sodium sulfonate by using the victory oil field mining injection water to obtain the heavy oil viscosity reducer, wherein the heavy oil viscosity reducer is used for the evaluation of the heavy oil viscosity reducing effect, the evaluation of interfacial tension and an oil displacement experiment, and the evaluation results of the heavy oil viscosity reducing effect and the interfacial tension are shown in the following table 3. Wherein, the compositions of the winning oil field winning injection water are shown in the table 1. The composition of the resulting viscosity reducer is shown in Table 2.
The result shows that the viscosity reducer improves the crude oil recovery by 10.1 percent.
Example 5
Synthesis of 1.1-octadecyl-4-nitroindane sulfonate
a) Adding 1.0mol of 1-octadecyl indane into a reactor provided with a condensing device and a stirring device, dropwise adding 1.5mol of fuming nitric acid, controlling the reaction temperature to be 50 ℃, and continuously reacting for 2 hours after dropwise adding is finished to obtain 0.80mol of 1-octadecyl-4-nitroindane;
b) Adding 0.80mol of 1-octadecyl-4-nitroindane synthesized in the step a) into a membrane type sulfonation reaction device, and introducing 1.5mol of SO 3 And controlling the reaction temperature to be 45 ℃, reacting for 30 minutes to obtain 0.72mol of 1-octadecyl-4-nitroindan-6-sulfonic acid, and adding sodium hydroxide to adjust the pH value to 9 to obtain the 1-octadecyl-4-nitroindan-6-sodium sulfonate.
2. Evaluation of viscosity reducer Performance
And (3) preparing 0.5wt% of the solution of the 1-octadecyl-4-nitroindan-6-sodium sulfonate by using the victory oil field winning injection water to obtain the thick oil viscosity reducer, wherein the thick oil viscosity reducer is used for thick oil viscosity reduction effect evaluation and interfacial tension evaluation, and the results are shown in the following table 3. Wherein, the compositions of the winning oil field winning injection water are shown in the table 1. The composition of the resulting viscosity reducer is shown in Table 2.
Example 6
Synthesis of 1.1-dodecyl-3-octyl-4-nitroindane sulfonate
The method is the same as example 3, except that 1-dodecyl-3-octylindane is used as the raw material to obtain 1-dodecyl-3-octylene-4-nitroindane sodium sulfonate.
2. Evaluation of viscosity reducer Performance
1wt% of 1-dodecyl-3-octyl-4-nitroindane sodium sulfonate solution is prepared by using victory oil field victory oil production injection water to obtain the heavy oil viscosity reducer, and the heavy oil viscosity reducer is used for the evaluation of the heavy oil viscosity reducing effect and the evaluation of interfacial tension, and the results are shown in the following table 3. Wherein, the compositions of the winning oil field winning injection water are shown in the table 1. The composition of the viscosity reducer is shown in Table 2.
Comparative example 1
The evaluation method is the same as that of example 3, except that sodium petroleum sulfonate (victory refinery) is used instead of sodium 1-dodecyl-4-nitroindan-6-sulfonate in example 3, and the results are shown in Table 3. The result shows that the obtained viscosity reducer improves the crude oil recovery by 1.6%.
TABLE 1 victory oilfield injection Water
TABLE 2 viscosity reducer composition
TABLE 3 oil-displacing agent Properties
| Viscosity reduction Rate (%) | Interfacial tension (mN/m) | |
| Example 1 | 85 | 0.0091 |
| Example 2 | 91 | 0.0071 |
| Example 3 | 96 | 0.0056 |
| Example 4 | 92 | 0.0064 |
| Example 5 | 98 | 0.0041 |
| Example 6 | 99.2 | 0.0048 |
| Comparative example 1 | 48 | 0.13 |
It should be noted that the above-mentioned embodiments are only for explaining the present invention, and do not constitute any limitation to the present invention. The present invention has been described with reference to exemplary embodiments, but the words which have been used herein are words of description and illustration, rather than words of limitation. The invention can be modified, as prescribed, within the scope of the claims and without departing from the scope and spirit of the invention. Although the invention has been described herein with reference to particular means, materials and embodiments, the invention is not intended to be limited to the particulars disclosed herein, but rather extends to all other methods and applications having the same functionality.
Claims (10)
1. A sulfonate thick oil viscosity reducer comprises at least one of compounds shown as the following formula I,
in the formula I, R 1 Is C 6 -C 30 A hydrocarbon group of R 2 Is H or C 1 -C 30 A hydrocarbon group of (a); m is alkali goldAnd n is the number of M which enables the compound shown in the formula I to be electrically neutral.
2. Viscosity reducer according to claim 1, wherein the alkali metal ion is a sodium ion or a potassium ion and the alkaline earth metal ion is a calcium ion or a magnesium ion, preferably n =1 when M is an alkali metal ion and n =0.5 when M is an alkaline earth metal ion.
3. Viscosity reducer according to claim 1 or 2, characterized in that in formula I, R is 1 Is C 6 -C 30 Alkyl groups of (a); preferably R 1 Is C 6 -C 20 More preferably C 8 -C 16 Alkyl groups of (a);
and/or R 2 Is H, or C 1 -C 30 Is preferably H or C 1 -C 18 Further preferably H or C 1 -C 6 Alkyl group of (1).
4. Viscosity reducer according to any of claims 1 to 3, characterized in that it comprises at least one of the compounds of formula I-1 below,
in the formula I-1, R 1 ，R 2 M and n have the same meanings as in formula I.
5. Viscosity reducer according to any of claims 1-4, characterized in that the viscosity reducer further comprises water with a total mineralization degree of 0-80000mg/L, preferably 100-30000mg/L, and the water has a mass content of 90-99.9 wt% based on the total mass of the viscosity reducer.
6. The process for preparing the viscosity reducer of any one of claims 1-5 comprising the steps of:
a) Mixing the compound shown in the formula II with a nitrating agent to carry out nitration reaction to obtain a nitration product shown in a formula III;
b) Mixing the obtained nitration product with a sulfonating agent to carry out sulfonation reaction to obtain a sulfonated product shown in a formula IV;
c) Mixing the obtained sulfonated product with alkali to obtain a compound shown in a formula I;
in the formulae II, III and IV, R 1 And R 2 Have the same definition as formula I;
preferably, the compound of formula II has a structure shown in formula II-1 below, the nitrated product of formula III has a structure shown in formula III-1 below, and the sulfonated product of formula IV has a structure shown in formula IV-1 below:
in the formulas II-1, III-1 and IV-1, R 1 And R 2 Have the same definition as formula I.
7. The method of claim 6, wherein the nitrating agent is nitric acid and/or dinitrogen pentoxide or a mixture of at least one of nitric acid and dinitrogen pentoxide with at least one of concentrated sulfuric acid, glacial acetic acid, acetic anhydride, and phosphorus pentoxide, and/or the sulfonating agent is selected from at least one of concentrated sulfuric acid, fuming sulfuric acid, and sulfur trioxide; and/or the base is at least one of an alkali metal hydroxide and an alkaline earth metal hydroxide, preferably sodium hydroxide and/or potassium hydroxide.
8. The process according to claim 6 or 7, wherein in step a), the molar ratio of the compound represented by formula II to the nitrating agent is (1; and/or in step b), the molar ratio of the nitrated product to the sulfonating agent is (1; and/or in step c) the amount of base added is such that the pH of the mixture of the sulfonated product and the base is adjusted to 7 to 14.
9. The process according to any one of claims 6 to 8, wherein in step a), the temperature of the nitration reaction is between 0 ℃ and 80 ℃ and the time of the nitration reaction is between 1h and 10h;
and/or in the step b), the temperature of the sulfonation reaction is 20-80 ℃, and the time of the sulfonation reaction is 0.5-10h.
10. Use of the viscosity reducer according to any one of claims 1 to 5 or prepared by the preparation method according to any one of claims 6 to 9 in heavy oil recovery.
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