CN108316903B - Method for improving mineralization resistance of thick oil emulsification viscosity reducer in thick oil exploitation - Google Patents
Method for improving mineralization resistance of thick oil emulsification viscosity reducer in thick oil exploitation Download PDFInfo
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- 230000033558 biomineral tissue development Effects 0.000 title claims abstract description 74
- 239000003638 chemical reducing agent Substances 0.000 title claims abstract description 74
- 238000000034 method Methods 0.000 title claims abstract description 39
- 238000004945 emulsification Methods 0.000 title description 25
- 229910001425 magnesium ion Inorganic materials 0.000 claims abstract description 91
- 239000011575 calcium Substances 0.000 claims abstract description 88
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 claims abstract description 85
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 claims abstract description 78
- 229910001424 calcium ion Inorganic materials 0.000 claims abstract description 77
- 239000008398 formation water Substances 0.000 claims abstract description 73
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 58
- 230000001804 emulsifying effect Effects 0.000 claims abstract description 54
- 125000000129 anionic group Chemical group 0.000 claims abstract description 38
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 30
- ZFXVRMSLJDYJCH-UHFFFAOYSA-N calcium magnesium Chemical compound [Mg].[Ca] ZFXVRMSLJDYJCH-UHFFFAOYSA-N 0.000 claims abstract description 13
- 238000004458 analytical method Methods 0.000 claims abstract description 10
- GVGUFUZHNYFZLC-UHFFFAOYSA-N dodecyl benzenesulfonate;sodium Chemical compound [Na].CCCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 GVGUFUZHNYFZLC-UHFFFAOYSA-N 0.000 claims description 66
- 229940080264 sodium dodecylbenzenesulfonate Drugs 0.000 claims description 66
- BCKXLBQYZLBQEK-KVVVOXFISA-M Sodium oleate Chemical compound [Na+].CCCCCCCC\C=C/CCCCCCCC([O-])=O BCKXLBQYZLBQEK-KVVVOXFISA-M 0.000 claims description 44
- BAERPNBPLZWCES-UHFFFAOYSA-N (2-hydroxy-1-phosphonoethyl)phosphonic acid Chemical compound OCC(P(O)(O)=O)P(O)(O)=O BAERPNBPLZWCES-UHFFFAOYSA-N 0.000 claims description 20
- 150000001732 carboxylic acid derivatives Chemical class 0.000 claims description 12
- 229920000141 poly(maleic anhydride) Polymers 0.000 claims description 11
- YDONNITUKPKTIG-UHFFFAOYSA-N [Nitrilotris(methylene)]trisphosphonic acid Chemical compound OP(O)(=O)CN(CP(O)(O)=O)CP(O)(O)=O YDONNITUKPKTIG-UHFFFAOYSA-N 0.000 claims description 9
- BDOYKFSQFYNPKF-UHFFFAOYSA-N 2-[2-[bis(carboxymethyl)amino]ethyl-(carboxymethyl)amino]acetic acid;sodium Chemical compound [Na].[Na].OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O BDOYKFSQFYNPKF-UHFFFAOYSA-N 0.000 claims description 5
- 239000003208 petroleum Substances 0.000 claims description 4
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 4
- 238000011084 recovery Methods 0.000 abstract description 5
- 239000003921 oil Substances 0.000 description 86
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 description 33
- 229960001484 edetic acid Drugs 0.000 description 33
- 239000000243 solution Substances 0.000 description 29
- 239000012267 brine Substances 0.000 description 20
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 20
- 239000003129 oil well Substances 0.000 description 18
- 239000011777 magnesium Substances 0.000 description 12
- 238000004090 dissolution Methods 0.000 description 11
- ZGTMUACCHSMWAC-UHFFFAOYSA-L EDTA disodium salt (anhydrous) Chemical compound [Na+].[Na+].OC(=O)CN(CC([O-])=O)CCN(CC(O)=O)CC([O-])=O ZGTMUACCHSMWAC-UHFFFAOYSA-L 0.000 description 10
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 10
- 229910052791 calcium Inorganic materials 0.000 description 10
- 229910052749 magnesium Inorganic materials 0.000 description 10
- 239000000839 emulsion Substances 0.000 description 9
- 230000000694 effects Effects 0.000 description 7
- 239000003109 Disodium ethylene diamine tetraacetate Substances 0.000 description 6
- 235000019301 disodium ethylene diamine tetraacetate Nutrition 0.000 description 6
- 238000002360 preparation method Methods 0.000 description 6
- 238000012216 screening Methods 0.000 description 5
- 238000006243 chemical reaction Methods 0.000 description 3
- 239000000295 fuel oil Substances 0.000 description 3
- 230000000873 masking effect Effects 0.000 description 3
- 230000001603 reducing effect Effects 0.000 description 3
- 238000012795 verification Methods 0.000 description 3
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 2
- ABLZXFCXXLZCGV-UHFFFAOYSA-N Phosphorous acid Chemical compound OP(O)=O ABLZXFCXXLZCGV-UHFFFAOYSA-N 0.000 description 2
- 238000013329 compounding Methods 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 230000003301 hydrolyzing effect Effects 0.000 description 2
- 239000007764 o/w emulsion Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- LSNNMFCWUKXFEE-UHFFFAOYSA-M Bisulfite Chemical compound OS([O-])=O LSNNMFCWUKXFEE-UHFFFAOYSA-M 0.000 description 1
- 239000004721 Polyphenylene oxide Substances 0.000 description 1
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000000536 complexating effect Effects 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 229910017053 inorganic salt Inorganic materials 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 231100000252 nontoxic Toxicity 0.000 description 1
- 230000003000 nontoxic effect Effects 0.000 description 1
- 229920000570 polyether Polymers 0.000 description 1
- 230000008092 positive effect Effects 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- LJRGBERXYNQPJI-UHFFFAOYSA-M sodium;3-nitrobenzenesulfonate Chemical compound [Na+].[O-][N+](=O)C1=CC=CC(S([O-])(=O)=O)=C1 LJRGBERXYNQPJI-UHFFFAOYSA-M 0.000 description 1
- 238000003786 synthesis reaction Methods 0.000 description 1
- 230000002194 synthesizing effect Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Environmental & Geological Engineering (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Edible Oils And Fats (AREA)
Abstract
The invention provides a method for improving the mineralization resistance of a thick oil emulsifying viscosity reducer and application thereof in thick oil exploitation. When the method is used for thick oil recovery, the method comprises the following steps: performing water sample analysis on formation water in a thick oil layer to be exploited to obtain the total molar concentration of calcium and magnesium ions in the formation water; adding an anionic emulsifying viscosity reducer and a calcium-magnesium ion shielding agent into the thick oil layer to be exploited; wherein the ratio of the molar concentration of the calcium and magnesium ion shielding agent in the formation water of the thick oil reservoir to be produced to the total molar concentration of calcium and magnesium ions in the formation water is (1-2): 1. The method can improve the mineralization resistance of the anionic emulsifying viscosity reducer, so that the emulsifying viscosity reducer which is high temperature resistant and high mineralization resistant is obtained, and when the emulsifying viscosity reducer is used for thick oil exploitation, the viscosity of the thick oil can be effectively reduced.
Description
Technical Field
The invention belongs to the technical field of thickened oil exploitation, and particularly relates to a method for improving the mineralization resistance of a thickened oil emulsifying viscosity reducer and application of the method in thickened oil exploitation.
Background
The emulsification and viscosity reduction is a commonly used method for thick oil recovery, and because an oil layer contains a large amount of formation water, the emulsification and viscosity reduction can be performed only when the injected emulsification and viscosity reduction agent has good compatibility with the formation water during thick oil recovery, so that the thick oil emulsification and viscosity reduction agent is required to have certain mineralization resistance. In recent years, with continuous exploitation of deep-well heavy oil reservoirs, a large number of high-temperature reservoirs appear, the temperature of part of reservoirs in part of time periods even reaches 300 ℃, and the requirement that the heavy oil emulsification viscosity reducer can resist high temperature is met.
At present, a lot of researches on the high-temperature-resistant and high-salinity-resistant emulsifying viscosity reducer are carried out by a plurality of scholars at home and abroad, and the researches show that: the anionic emulsifying viscosity reducer has good high-temperature resistance, but the mineralization resistance is generally poor; the non-ionic emulsifying viscosity reducer generally has good mineralization resistance, but poor high-temperature resistance. Therefore, there are two main methods for developing an emulsifying viscosity reducer which is resistant to high temperature and hypersalinity: one is to adopt anionic emulsification viscosity reducer and nonionic emulsification viscosity reducer to compound, for example: qianjianhua and the like are mixed by an anionic emulsifying viscosity reducer, a small amount of inorganic salt, a non-ionic emulsifying viscosity reducer and water according to a certain proportion to form a compound high-temperature-resistant emulsifying viscosity reducer which is used for exploiting thick oil by injecting steam, the viscosity reduction rate of the emulsifying viscosity reducer reaches 99.1 percent and can resist the high temperature of 300 ℃; the other is to synthesize a novel emulsifying viscosity reducer integrating anionic and nonionic groups, such as: the sulfonic acid, carboxylic acid and polyether copolycondensation type emulsification viscosity reducer S-5 is synthesized by Qinling ice, etc., can resist the ultra-high temperature of 350 deg.C and resist salt>100000 mg/L (wherein, Ca)2+、Mg2+The content is more than 2000mg/L), has good viscosity reduction effect on super-thick oil such as victory, Liaohe and the like.
However, the above two preparation methods still have some disadvantages in the application of thick oil recovery, such as:
(1) the preparation method of compounding the anionic emulsifying viscosity reducer and the nonionic emulsifying viscosity reducer is adopted, and the emulsifying viscosity reducer has stronger selectivity to thick oil and larger compounding workload, so that the preparation cost is higher;
(2) the novel emulsification viscosity reducer synthesized by synthesizing comprehensive anionic and nonionic groups has the advantages of long synthesis period, more byproducts, complex preparation procedures and higher preparation cost.
Therefore, how to provide a simpler and lower-cost method for obtaining the high-temperature-resistant and hypersalinity-resistant emulsification viscosity reducer for thick oil exploitation is a technical problem which needs to be solved urgently at present.
Disclosure of Invention
Aiming at the technical problems, the invention provides a method for improving the mineralization resistance of a thick oil emulsification viscosity reducer and application of the method in thick oil exploitation.
In order to achieve the purpose, the invention adopts the technical scheme that:
the invention provides a method for improving the mineralization resistance of a thick oil emulsifying viscosity reducer, which comprises the process of adding a calcium-magnesium ion shielding agent into an anionic emulsifying viscosity reducer.
Preferably, the calcium and magnesium ion screening agent is any one selected from disodium ethylenediamine tetraacetic acid, hydrolyzed polymaleic anhydride, aminotrimethylenephosphonic acid, hydroxyethylidene diphosphonic acid and organophosphorus carboxylic acid.
Preferably, the anionic emulsifying viscosity reducer is selected from any one of sodium dodecyl benzene sulfonate, sodium oleate and petroleum sulfonate.
The invention also provides application of the method for improving the mineralization resistance of the thick oil emulsification viscosity reducer in the thick oil exploitation, which comprises the following steps:
performing water sample analysis on formation water in a thick oil layer to be exploited to obtain the total molar concentration of calcium and magnesium ions in the formation water;
adding an anionic emulsifying viscosity reducer and a calcium-magnesium ion shielding agent into the thick oil layer to be exploited; wherein the ratio of the molar concentration of the calcium and magnesium ion shielding agent in the formation water of the thick oil reservoir to be produced to the total molar concentration of calcium and magnesium ions in the formation water is (1-2): 1.
Preferably, the mass fraction of the anionic emulsifying viscosity reducer in the formation water of the thick oil reservoir to be recovered is 1%.
Compared with the prior art, the invention has the advantages and positive effects that:
1. according to the method for improving the mineralization resistance of the thick oil emulsification viscosity reducer, the calcium and magnesium ion shielding agent is added into the anionic emulsification viscosity reducer to complex calcium and magnesium ions in formation water, so that the anionic emulsification viscosity reducer can be well compatible with the formation water, and the mineralization resistance of the anionic emulsification viscosity reducer is effectively improved;
2. the method for improving the mineralization resistance of the thick oil emulsifying viscosity reducer provided by the invention is simple to operate, low in cost and wide in application range;
3. because the anionic emulsifying viscosity reducer has good high-temperature resistance, the method for improving the mineralization resistance of the thick oil emulsifying viscosity reducer can further improve the mineralization resistance of the thick oil emulsifying viscosity reducer, so that a single anionic emulsifying viscosity reducer can achieve the effects of temperature resistance and mineralization resistance;
4. when the method for improving the mineralization resistance of the thick oil emulsification viscosity reducer provided by the invention is applied to thick oil exploitation, thick oil can form an oil-in-water emulsion, the viscosity of the thick oil is effectively reduced, and the viscosity reduction rate is over 99%.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The embodiment of the invention provides a method for improving the mineralization resistance of a thick oil emulsifying viscosity reducer, which comprises the process of adding a calcium-magnesium ion shielding agent into an anionic emulsifying viscosity reducer. The calcium-magnesium ion masking agent is a masking agent capable of simultaneously masking calcium ions and magnesium ions by complexing. As the inventor finds that: the main reason for the poor compatibility of the anionic emulsifying viscosity reducer with the formation water is calcium and magnesium ions in the formation water, and therefore, in the embodiment, the calcium and magnesium ion shielding agent is added into the anionic emulsifying viscosity reducer to complex the calcium and magnesium ions in the formation water, so that the anionic emulsifying viscosity reducer can be well compatible with the formation water, and the mineralization resistance of the anionic emulsifying viscosity reducer is effectively improved. The method is simple to operate, low in cost and wide in application range. Meanwhile, the anionic emulsifying viscosity reducer has good high-temperature resistance, so that the mineralization resistance of the anionic emulsifying viscosity reducer can be further improved by the method provided by the invention, and the emulsifying viscosity reducer with high-temperature resistance and high-mineralization resistance can be further obtained.
In a preferred embodiment, the calcium-magnesium ion screening agent is selected from any one of disodium ethylenediaminetetraacetate, hydrolyzed polymaleic anhydride, aminotrimethylenephosphonic acid, hydroxyethylidene diphosphonic acid and organophosphorus carboxylic acid. In the preferred embodiment, the type of the calcium-magnesium ion screening agent is specifically defined, and the optimum screening effect can be obtained by using disodium Ethylenediaminetetraacetate (EDTA), hydrolyzed polymaleic anhydride (HPMA), aminotrimethylenephosphonic Acid (ATMP), hydroxyethylidene diphosphonic acid (HEDP), or organophosphorous carboxylic acid (PBTCA) as the calcium-magnesium ion screening agent. Particularly, disodium Ethylene Diamine Tetraacetate (EDTA) is cheap and easily available, non-toxic, harmless, green and environment-friendly, and is the best calcium and magnesium ion shielding agent. It is understood that the skilled person can also specifically select a suitable calcium and magnesium ion shielding agent according to the actual use requirement as long as the calcium and magnesium ions in the formation water can be shielded.
In a further preferred embodiment, the anionic emulsifying viscosity reducer is selected from any one of sodium dodecyl benzene sulfonate, sodium oleate and petroleum sulfonate. In the preferred embodiment, the anionic emulsifying viscosity reducer is further specified, because when disodium ethylenediaminetetraacetic acid (EDTA), hydrolyzed polymaleic anhydride (HPMA), aminotrimethylenephosphonic Acid (ATMP), hydroxyethylidene diphosphonic acid (HEDP), or organophosphorous carboxylic acid (PBTCA) is used as the calcium magnesium ion shielding agent, it has the best effect of improving the mineralization resistance of sodium dodecylbenzenesulfonate, sodium oleate, or petroleum sulfonate. It is understood that those skilled in the art can specifically select a suitable anionic emulsifying viscosity reducer according to the actual use requirement.
The invention also provides application of the method for improving the mineralization resistance of the thick oil emulsification viscosity reducer in the thick oil exploitation, which comprises the following steps:
s1: performing water sample analysis on formation water in a thick oil layer to be exploited to obtain the total molar concentration of calcium and magnesium ions in the formation water;
s2: adding an anionic emulsifying viscosity reducer and a calcium-magnesium ion shielding agent into the thick oil layer to be exploited; wherein the ratio of the molar concentration of the calcium and magnesium ion shielding agent in the formation water of the thick oil reservoir to be produced to the total molar concentration of calcium and magnesium ions in the formation water is (1-2): 1.
In the application, the total molar concentration of calcium and magnesium ions in the formation water is obtained through water sample analysis, so that the addition amount of the calcium and magnesium ion shielding agent can be calculated, the calcium and magnesium ion shielding agent can be added to shield the calcium ions and the magnesium ions in the formation water, the anionic type emulsification viscosity reducer is well compatible with the formation water, the anionic type emulsification viscosity reducer is not inactivated, and the effect of reducing the viscosity of the thick oil is achieved. It should be noted that when the ratio of the molar concentration of the calcium and magnesium ion shielding agent in the formation water to the total molar concentration of calcium and magnesium ions in the formation water is (1-2):1, the calcium and magnesium ions in the formation water can be completely shielded by the added calcium and magnesium ion shielding agent.
In a preferred embodiment, the mass fraction of the anionic emulsifying viscosity reducer in the formation water of the thick oil reservoir to be recovered is 1%. In the preferred embodiment, the addition amount of the anionic emulsifying viscosity reducer is specifically defined, and the addition amount is the optimal addition amount when the thick oil is produced. It is understood that other suitable addition amounts may be selected by those skilled in the art depending on the actual production conditions.
In order to more clearly and specifically describe the method for improving the mineralization resistance of the thick oil emulsifying viscosity reducer provided by the embodiment of the invention and the application of the method in thick oil recovery, the following description is given with reference to the specific embodiment.
It should be noted that the simulated brine used in the following examples was prepared by the following method: the viscosity-reducing agent is prepared according to a preparation method of simulated brine in high-temperature emulsification viscosity-reducing general technical conditions (Q/SH 10202193-2013), and the specific formula is shown in Table 1:
TABLE 1 simulated brine composition
Example 1
Disodium Ethylene Diamine Tetraacetate (EDTA) was added to Sodium Dodecylbenzenesulfonate (SDBS), and the variation of the mineralization resistance of sodium dodecylbenzenesulfonate was verified using mineralized water of various degrees of mineralization, simulated saline water and middle sea oil LD5-2N-2 oil well formation water, and the results are shown in Table 2. Wherein, the addition amount of the ethylene diamine tetraacetic acid disodium is as follows: the molar concentration of the ethylene diamine tetraacetic acid disodium in mineralized water, simulated salt water or middle sea oil LD5-2N-2 oil well formation water is the same as the total molar concentration of calcium and magnesium ions in the water.
TABLE 2 dissolution of SDBS in mineralized water of different mineralization before and after EDTA addition
As can be seen from Table 2, when SDBS is dissolved in mineralized water containing calcium and magnesium ions, clear and transparent solutions cannot be obtained, which indicates that SDBS and mineralized water containing calcium and magnesium ions cannot be well compatible, and the mineralization resistance of SDBS to calcium and magnesium is poor. After EDTA is added, a clear and transparent solution can be obtained, so that after the EDTA is added, the SDBS can be well compatible with mineralized water containing calcium and magnesium ions, and the mineralization resistance of the SDBS is obviously improved.
Example 2
Disodium ethylenediaminetetraacetic acid (EDTA) was added to sodium oleate, and the variation in the mineralization resistance of sodium oleate was verified using mineralized water of different degrees of mineralization, simulated brine, and Mediterranean oil LD5-2N-2 well formation water, the results of which are shown in Table 3. Wherein, the addition amount of the ethylene diamine tetraacetic acid disodium is as follows: the molar concentration of the ethylene diamine tetraacetic acid disodium in mineralized water, simulated salt water or middle sea oil LD5-2N-2 oil well formation water is the same as the total molar concentration of calcium and magnesium ions in the water.
TABLE 3 dissolution of sodium oleate in mineralized water of different mineralization before and after EDTA addition
As can be seen from table 3, when sodium oleate is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that sodium oleate and mineralized water containing calcium and magnesium ions cannot be well compatible, and the mineralization resistance of sodium oleate to calcium and magnesium is poor. After EDTA is added, clear and transparent solution can be obtained, so that after the EDTA is added, the sodium oleate can be well compatible with mineralized water containing calcium and magnesium ions, and the mineralization resistance of the sodium oleate is obviously improved.
Example 3
The results of changes in the mineralization resistance of sodium dodecylbenzene sulfonate (SDBS) were confirmed by adding hydrolyzed polymaleic anhydride (HPMA) to the sodium dodecylbenzene sulfonate (SDBS) and using simulated brine and medium sea oil LD5-2N-2 well formation water, and are shown in Table 4. Wherein the addition amount of the hydrolytic polymaleic anhydride is as follows: the molar concentration of hydrolyzed polymaleic anhydride in the simulated brine or oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 4 dissolution of SDBS in mineralized water of different mineralization before and after HPMA addition
As can be seen from table 4, when SDBS is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that SDBS and mineralized water containing calcium and magnesium ions cannot be well compatible, and the resistance of SDBS to calcium and magnesium mineralization is poor. After the HPMA is added, clear and transparent solution can be obtained, so that the SDBS can be well compatible with mineralized water containing calcium and magnesium ions after the HPMA is added, and the mineralization resistance of the SDBS is obviously improved.
Example 4
Hydrolyzed polymaleic anhydride (HPMA) was added to sodium oleate and the sodium oleate was tested for changes in its resistance to mineralization using simulated brine and Mediterranean oil LD5-2N-2 well formation water, the results of which are shown in Table 5. Wherein the addition amount of the hydrolytic polymaleic anhydride is as follows: the molar concentration of hydrolyzed polymaleic anhydride in the simulated brine or oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 5 dissolution of sodium oleate in mineralized water of different mineralization before and after HPMA addition
As can be seen from table 5, when sodium oleate is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that sodium oleate and mineralized water containing calcium and magnesium ions cannot be well compatible, and the mineralization resistance of sodium oleate to calcium and magnesium is poor. After the HPMA is added, clear and transparent solution can be obtained, so that the sodium oleate can be well compatible with mineralized water containing calcium and magnesium ions after the HPMA is added, and the mineralization resistance of the sodium oleate is obviously improved.
Example 5
Aminotrimethylidene phosphonic Acid (ATMP) was added to Sodium Dodecylbenzenesulfonate (SDBS) and the results of the changes in the mineralization resistance of the sodium dodecylbenzenesulfonate were examined using simulated brine and Mediterranean oil LD5-2N-2 well formation water, as shown in Table 6. Wherein, the addition amount of the amino trimethylene phosphonic acid is as follows: the molar concentration of the amino trimethylene phosphonic acid in the simulated brine or oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 6 dissolution of SDBS in mineralized water of different mineralization before and after ATMP addition
As can be seen from table 6, when SDBS is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that SDBS cannot be well compatible with mineralized water containing calcium and magnesium ions, and SDBS has poor resistance to calcium and magnesium mineralization. After ATMP is added, clear and transparent solution can be obtained, so that after ATMP is added, SDBS can be well compatible with mineralized water containing calcium and magnesium ions, and the mineralization resistance of SDBS is obviously improved.
Example 6
Aminotrimethylidene phosphonic Acid (ATMP) was added to sodium oleate and the sodium oleate was tested for changes in its ability to resist mineralization using simulated brine and Mediterranean oil LD5-2N-2 well formation water, the results of which are shown in Table 7. Wherein, the addition amount of the amino trimethylene phosphonic acid is as follows: the molar concentration of the amino trimethylene phosphonic acid in the simulated brine or oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 7 dissolution of sodium oleate in mineralized water of different mineralization before and after ATMP addition
As can be seen from table 7, when sodium oleate is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that sodium oleate and mineralized water containing calcium and magnesium ions cannot be well compatible, and the mineralization resistance of sodium oleate to calcium and magnesium is poor. After ATMP is added, clear and transparent solution can be obtained, so that sodium oleate can be well compatible with mineralized water containing calcium and magnesium ions after ATMP is added, and the mineralization resistance of the sodium oleate is obviously improved.
Example 7
Sodium Dodecylbenzenesulfonate (SDBS) was added with hydroxyethylidene diphosphonic acid (HEDP) and the mineralization resistance of the sodium dodecylbenzenesulfonate was examined with a simulated brine and middle sea oil LD5-2N-2 well formation water, the results of which are shown in Table 8. Wherein, the adding amount of the hydroxyethylidene diphosphonic acid is as follows: the molar concentration of hydroxyethylidene diphosphonic acid in the simulated brine or oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 8 dissolution of SDBS in mineralized water of different mineralization before and after HEDP addition
As can be seen from table 8, when SDBS is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that SDBS cannot be well compatible with mineralized water containing calcium and magnesium ions, and SDBS has poor resistance to calcium and magnesium mineralization. When HEDP is added, clear and transparent solution can be obtained, so that SDBS can be well compatible with mineralized water containing calcium and magnesium ions after HEDP is added, and the mineralization resistance of SDBS is obviously improved.
Example 8
Hydroxyethylidene diphosphonic acid (HEDP) was added to sodium oleate and the variation in the mineralization resistance of sodium oleate was verified using simulated brine and Mediterranean oil LD5-2N-2 well formation water, the results of which are shown in Table 9. Wherein, the adding amount of the hydroxyethylidene diphosphonic acid is as follows: the molar concentration of hydroxyethylidene diphosphonic acid in the simulated brine or oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 9 dissolution of sodium oleate in mineralized water of different mineralization before and after HEDP addition
As can be seen from table 9, when sodium oleate is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that sodium oleate and mineralized water containing calcium and magnesium ions cannot be well compatible, and the mineralization resistance of sodium oleate to calcium and magnesium is poor. After HEDP is added, a clear and transparent solution can be obtained, so that sodium oleate can be well compatible with mineralized water containing calcium and magnesium ions, and the mineralization resistance of the sodium oleate is obviously improved.
Example 9
Organophosphorus carboxylic acid (PBTCA) was added to Sodium Dodecylbenzenesulfonate (SDBS), and the variation in the mineralization resistance of sodium dodecylbenzenesulfonate was verified using simulated brine and Middai oil LD5-2N-2 well formation water, and the results are shown in Table 10. Wherein, the adding amount of the organophosphorus carboxylic acid is as follows: the molar concentration of the organophosphorus carboxylic acid in the simulated brine or the oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 10 dissolution of SDBS in mineralized water of different mineralization before and after PBTCA addition
As can be seen from table 10, when SDBS is dissolved in mineralized water containing calcium and magnesium ions, no clear and transparent solution can be obtained, which indicates that SDBS and mineralized water containing calcium and magnesium ions cannot be well compatible, and the resistance of SDBS to calcium and magnesium mineralization is poor. After PBTCA is added, clear and transparent solution can be obtained, so that after PBTCA is added, SDBS can be well compatible with mineralized water containing calcium and magnesium ions, and the mineralization resistance of SDBS is obviously improved.
Example 10
Organophosphorus carboxylic acid (PBTCA) was added to sodium oleate and the sodium oleate was tested for changes in its ability to resist mineralization using simulated brine and Mediterranean oil LD5-2N-2 well formation water, the results of which are shown in Table 11. Wherein, the adding amount of the organophosphorus carboxylic acid is as follows: the molar concentration of the organophosphorus carboxylic acid in the simulated brine or the oil well formation water is the same as the total molar concentration of calcium and magnesium ions therein.
TABLE 11 dissolution of sodium oleate in mineralized water of different mineralization before and after PBTCA addition
As can be seen from table 11, when sodium oleate is dissolved in mineralized water containing calcium and magnesium ions, a clear and transparent solution cannot be obtained, which indicates that sodium oleate and mineralized water containing calcium and magnesium ions cannot be well compatible, and the mineralization resistance of sodium oleate to calcium and magnesium is poor. After PBTCA is added, clear and transparent solution can be obtained, so that sodium oleate can be well compatible with mineralized water containing calcium and magnesium ions after PBTCA is added, and the mineralization resistance of sodium oleate is obviously improved.
The application of the method for improving the mineralization resistance of the thick oil emulsifying viscosity reducer provided by the invention in thick oil exploitation is illustrated below by taking Sodium Dodecyl Benzene Sulfonate (SDBS) as an anionic emulsifying viscosity reducer and disodium Ethylene Diamine Tetraacetic Acid (EDTA) as a calcium-magnesium ion shielding agent.
Example 11
(1) Water sample analysis was performed on the formation water in the middle sea oil LD5-2N-2 oil well, the analysis results are shown in Table 12, and the total molar concentration of calcium and magnesium ions in the formation water of the middle sea oil LD5-2N-2 oil well was found to be 6.536X 10-2mol/L。
TABLE 12 results of analysis of formation water samples of the marine oil LD5-2N-2 oil well
(2) Adding Sodium Dodecyl Benzene Sulfonate (SDBS) and disodium Ethylene Diamine Tetraacetate (EDTA) into the thick oil layer to be exploited; wherein the molar concentration of the Ethylene Diamine Tetraacetic Acid (EDTA) in the formation water is 6.536 multiplied by 10-2mol/L, namely the ratio of the molar concentration of Ethylene Diamine Tetraacetic Acid (EDTA) in the formation water to the total molar concentration of calcium and magnesium ions in the formation water is 1:1 (n)EDTA：nCa+Mg1: 1) (ii) a The mass fraction of Sodium Dodecyl Benzene Sulfonate (SDBS) in the formation water is 1%.
Example 12
(1) Water sample analysis was performed on the formation water in the middle sea oil LD5-2N-2 oil well, the analysis results are shown in Table 12, and the total molar concentration of calcium and magnesium ions in the formation water of the middle sea oil LD5-2N-2 oil well was found to be 6.536X 10-2mol/L。
(2) To the belt openingAdding Sodium Dodecyl Benzene Sulfonate (SDBS) and disodium Ethylene Diamine Tetraacetate (EDTA) into the heavy oil extraction oil layer; wherein the molar concentration of the Ethylene Diamine Tetraacetic Acid (EDTA) in the formation water is 1.307 multiplied by 10-1mol/L, namely the ratio of the molar concentration of Ethylene Diamine Tetraacetic Acid (EDTA) in the formation water to the total molar concentration of calcium and magnesium ions in the formation water is 2:1 (n)EDTA：nCa+Mg2: 1) (ii) a The mass fraction of Sodium Dodecyl Benzene Sulfonate (SDBS) in the formation water is 1%.
Verification of mineralization resistance
The results of observing the dissolution of SDBS by adding EDTA in various proportions to the formation water of the medium sea oil LD5-2N-2 well are shown in Table 13.
TABLE 13 mineralization resistance test results
From table 13, it can be seen that when the ratio of the molar concentration of EDTA added in the formation water to the total molar concentration of calcium and magnesium ions in the formation water is 1:1 or 2:1, a clear and transparent solution can be obtained, thereby indicating that: in examples 11 and 12, SDBS was well compatible with medium sea oil LD5-2N-2 well formation water.
Verification of viscosity reduction effect of thick oil
The viscosity reducing effect of the thick oil of example 11 and example 12 was verified according to the thick oil emulsification viscosity reducing standard (Q/SH 10201519-2013). The method comprises the following specific steps: preparing SDBS into a solution with the mass fraction of 1% by using middle-sea oil LD5-2N-2 oil well formation water, adding EDTA (ethylene diamine tetraacetic acid) with different proportions, and uniformly mixing with the thickened oil to obtain a thickened oil emulsion, wherein the mass ratio of the thickened oil to the prepared SDBS and EDTA solution is 70: 30. The thick oil emulsion is placed at the constant temperature of 50 +/-1 ℃ for 1h, stirred at the rotating speed of 250r/min for 2min, the viscosity mu of the thick oil emulsion at the temperature of 50 +/-1 ℃ is rapidly measured by a rotational viscometer, the corresponding viscosity reduction rate is calculated, and the calculation results are shown in table 14. Wherein, the formula for calculating the viscosity reduction rate is as follows:
wherein f is the viscosity reduction rate; mu.s0The viscosity of the thick oil at 50 +/-1 ℃ is 7650mPa & s; mu is the viscosity of the thick oil emulsion measured at 50. + -. 1 ℃.
TABLE 14 viscosity reduction ratio of Thick oil and average interfacial tension of Thick oil emulsion
From table 14, when the method for improving the mineralization resistance of the thick oil emulsification viscosity reducer provided by the invention is applied to thick oil exploitation, the thick oil can form an oil-in-water type emulsion, the viscosity of the thick oil is effectively reduced, and the viscosity reduction rate is more than 99%.
Numerous studies have shown that interfacial tension is an important indicator of whether the oil-in-water emulsion formed by the reaction is stable, and therefore, the average interfacial tension of the thick oil emulsion was measured, and the results are shown in Table 14. As can be seen from Table 14, the addition of EDTA keeps the interfacial tension of the emulsion system containing calcium and magnesium ions to a small value, which is favorable for the stability of the thick oil emulsion.
Verification of temperature resistance
Preparing SDBS into a solution with the mass fraction of 1% by using middle sea oil LD5-2N-2 oil well formation water, adding EDTA (ethylene diamine tetraacetic acid) with different proportions, then placing the solution into a high-pressure reaction kettle for sealing, then placing the high-pressure reaction kettle into a muffle furnace with the temperature of 300 ℃ for high-temperature burning for 24 hours, opening the kettle after naturally cooling, pouring out the solution, observing the property change of the solution, and measuring the viscosity reduction effect of the solution on thick oil, wherein the results are shown in Table 15.
TABLE 15 test results of temperature resistance
As can be seen from Table 15, the addition of EDTA did not affect the original high temperature resistance of the anionic emulsifying viscosity reducer SDBS after the treatment at a high temperature of 300 ℃.
Claims (3)
1. The method for improving the mineralization resistance of the thick oil emulsifying viscosity reducer in thick oil exploitation is characterized by comprising the following steps: comprises the process of adding a calcium-magnesium ion shielding agent into an anionic emulsifying viscosity reducer; the calcium and magnesium ion shielding agent is selected from any one of ethylene diamine tetraacetic acid disodium, hydrolyzed polymaleic anhydride, amino trimethylene phosphonic acid, hydroxyethylidene diphosphonic acid and organophosphorus carboxylic acid;
the method specifically comprises the following steps:
performing water sample analysis on formation water in a thick oil layer to be exploited to obtain the total molar concentration of calcium and magnesium ions in the formation water;
adding an anionic emulsifying viscosity reducer and a calcium-magnesium ion shielding agent into the thick oil layer to be exploited; wherein the ratio of the molar concentration of the calcium and magnesium ion shielding agent in the formation water of the thick oil reservoir to be produced to the total molar concentration of calcium and magnesium ions in the formation water is (1-2): 1.
2. The method for improving the mineralization resistance of the thick oil emulsifying viscosity reducer in thick oil exploitation according to claim 1, wherein the method comprises the following steps: the anionic emulsifying viscosity reducer is selected from any one of sodium dodecyl benzene sulfonate, sodium oleate and petroleum sulfonate.
3. The method for improving the mineralization resistance of the thick oil emulsifying viscosity reducer in thick oil exploitation according to claim 1, wherein the method comprises the following steps: the mass fraction of the anionic emulsifying viscosity reducer in the formation water of the thick oil layer to be exploited is 1%.
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