CN111662699A - Oilfield polymer viscosity loss inhibitor and application method thereof - Google Patents
Oilfield polymer viscosity loss inhibitor and application method thereof Download PDFInfo
- Publication number
- CN111662699A CN111662699A CN202010546691.0A CN202010546691A CN111662699A CN 111662699 A CN111662699 A CN 111662699A CN 202010546691 A CN202010546691 A CN 202010546691A CN 111662699 A CN111662699 A CN 111662699A
- Authority
- CN
- China
- Prior art keywords
- polymer
- oilfield
- inhibitor
- viscosity loss
- polymer viscosity
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 229920000642 polymer Polymers 0.000 title claims abstract description 106
- 239000003112 inhibitor Substances 0.000 title claims abstract description 61
- 238000000034 method Methods 0.000 title claims abstract description 25
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 46
- 239000012452 mother liquor Substances 0.000 claims abstract description 18
- HEMHJVSKTPXQMS-UHFFFAOYSA-M sodium hydroxide Inorganic materials [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims abstract description 17
- LPXPTNMVRIOKMN-UHFFFAOYSA-M sodium nitrite Chemical compound [Na+].[O-]N=O LPXPTNMVRIOKMN-UHFFFAOYSA-M 0.000 claims abstract description 9
- 235000015097 nutrients Nutrition 0.000 claims abstract description 8
- 230000002195 synergetic effect Effects 0.000 claims abstract description 7
- 229920002401 polyacrylamide Polymers 0.000 claims description 8
- FGIUAXJPYTZDNR-UHFFFAOYSA-N potassium nitrate Chemical compound [K+].[O-][N+]([O-])=O FGIUAXJPYTZDNR-UHFFFAOYSA-N 0.000 claims description 8
- VWDWKYIASSYTQR-UHFFFAOYSA-N sodium nitrate Chemical compound [Na+].[O-][N+]([O-])=O VWDWKYIASSYTQR-UHFFFAOYSA-N 0.000 claims description 8
- IOVCWXUNBOPUCH-UHFFFAOYSA-M Nitrite anion Chemical compound [O-]N=O IOVCWXUNBOPUCH-UHFFFAOYSA-M 0.000 claims description 5
- 239000000203 mixture Substances 0.000 claims description 5
- 238000007865 diluting Methods 0.000 claims description 4
- 235000010333 potassium nitrate Nutrition 0.000 claims description 4
- 239000004323 potassium nitrate Substances 0.000 claims description 4
- 239000011684 sodium molybdate Substances 0.000 claims description 4
- 235000015393 sodium molybdate Nutrition 0.000 claims description 4
- TVXXNOYZHKPKGW-UHFFFAOYSA-N sodium molybdate (anhydrous) Chemical compound [Na+].[Na+].[O-][Mo]([O-])(=O)=O TVXXNOYZHKPKGW-UHFFFAOYSA-N 0.000 claims description 4
- 235000010344 sodium nitrate Nutrition 0.000 claims description 4
- 239000004317 sodium nitrate Substances 0.000 claims description 4
- 235000010288 sodium nitrite Nutrition 0.000 claims description 4
- 238000003756 stirring Methods 0.000 claims description 4
- APUPEJJSWDHEBO-UHFFFAOYSA-P ammonium molybdate Chemical compound [NH4+].[NH4+].[O-][Mo]([O-])(=O)=O APUPEJJSWDHEBO-UHFFFAOYSA-P 0.000 claims description 3
- 239000011609 ammonium molybdate Substances 0.000 claims description 3
- 235000018660 ammonium molybdate Nutrition 0.000 claims description 3
- 229940010552 ammonium molybdate Drugs 0.000 claims description 3
- 230000002572 peristaltic effect Effects 0.000 claims description 3
- 238000005086 pumping Methods 0.000 claims description 3
- 125000000129 anionic group Chemical group 0.000 claims description 2
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims 2
- 239000002351 wastewater Substances 0.000 claims 2
- 229910021529 ammonia Inorganic materials 0.000 claims 1
- MEFBJEMVZONFCJ-UHFFFAOYSA-N molybdate Chemical compound [O-][Mo]([O-])(=O)=O MEFBJEMVZONFCJ-UHFFFAOYSA-N 0.000 claims 1
- 239000000126 substance Substances 0.000 claims 1
- 238000002360 preparation method Methods 0.000 abstract description 5
- 239000012752 auxiliary agent Substances 0.000 abstract 1
- 241000894006 Bacteria Species 0.000 description 13
- 239000000243 solution Substances 0.000 description 10
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 description 8
- 229910001448 ferrous ion Inorganic materials 0.000 description 8
- 239000010865 sewage Substances 0.000 description 8
- 150000001450 anions Chemical class 0.000 description 6
- 238000002347 injection Methods 0.000 description 6
- 239000007924 injection Substances 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 4
- 241000295146 Gallionellaceae Species 0.000 description 3
- 239000003814 drug Substances 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000012360 testing method Methods 0.000 description 3
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 2
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 2
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 2
- 230000000844 anti-bacterial effect Effects 0.000 description 2
- 230000001580 bacterial effect Effects 0.000 description 2
- 239000003899 bactericide agent Substances 0.000 description 2
- 229910001424 calcium ion Inorganic materials 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 229910017053 inorganic salt Inorganic materials 0.000 description 2
- 150000002500 ions Chemical class 0.000 description 2
- 229910001425 magnesium ion Inorganic materials 0.000 description 2
- 230000003647 oxidation Effects 0.000 description 2
- 238000007254 oxidation reaction Methods 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 238000005273 aeration Methods 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 230000000536 complexating effect Effects 0.000 description 1
- 239000008139 complexing agent Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000000354 decomposition reaction Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 238000006056 electrooxidation reaction Methods 0.000 description 1
- 238000003912 environmental pollution Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- -1 iron ions Chemical class 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000012528 membrane Substances 0.000 description 1
- 230000002503 metabolic effect Effects 0.000 description 1
- 230000004060 metabolic process Effects 0.000 description 1
- 229910021645 metal ion Inorganic materials 0.000 description 1
- 244000005700 microbiome Species 0.000 description 1
- 238000001728 nano-filtration Methods 0.000 description 1
- 231100000252 nontoxic Toxicity 0.000 description 1
- 230000003000 nontoxic effect Effects 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000007539 photo-oxidation reaction Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000001223 reverse osmosis Methods 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 239000011206 ternary composite Substances 0.000 description 1
- 238000005303 weighing Methods 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
- C09K8/58—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
- C09K8/588—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 polymers
-
- 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/845—Compositions based on water or polar solvents containing inorganic compounds
-
- 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/882—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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)
- Oil, Petroleum & Natural Gas (AREA)
- Inorganic Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
Abstract
The invention discloses an oilfield polymer viscosity loss inhibitor and a using method thereof, and relates to an oilfield polymer viscosity loss inhibitor and a using method thereof. The invention aims to solve the problems of unstable viscosity and large loss of polymer in the process of injecting the conventional preparation polymer into the underground. The auxiliary agent is prepared from nitrite, sodium hydroxide, nutrient elements, a synergistic inhibitor and water according to the mass percentage. The viscosity loss inhibitor of the oil field polymer is used for preparing polymer mother liquor and diluted polymer and then used for oil exploitation.
Description
Technical Field
The invention relates to an oilfield polymer viscosity loss inhibitor and a use method thereof.
Background
Along with the continuous development of oil field exploitation, the water content of the produced liquid of the conventional water-drive oil extraction method is higher and higher, and the oil field yield is reduced, so that the oil extraction technical progress is promoted, and the oil field recovery ratio is improved. The oil displacement technology is a ternary composite oil displacement technology which utilizes polymer, alkali and surfactant and is widely used in oil fields. Along with the gradual increase of the exploitation scale, the water consumption is gradually increased, and the serious environmental pollution can be caused by the large discharge of the oilfield produced water, so that in order to reduce the use amount of clean water and the sewage discharge amount of the oilfield, the oilfield generally adopts sewage to prepare polymers for oil exploitation.
The produced water in oil field has complex composition and high mineralization degree, and contains a large amount of inorganic salt ions, such as Na+、Mg2+、Ca2+、Cl-、SO4 2-And the like, microorganisms and petroleum hydrocarbons can cause viscosity loss of polymers in the preparation process to influence oil exploitation, and similarly, water quality change, bacterial decomposition, iron ions, pipeline corrosion and the like can cause loss of polymers in the preparation process of the polymers to cause continuous reduction of the viscosity of the polymers, and the viscosity loss can reach 40% or even higher in the process of preparing the polymers and injecting the polymers into the ground, so that the oil exploitation is influenced. The method for improving the polymer concentration is mainly adopted to ensure that the viscosity of the injection wellhead meets the relevant requirements, so that the exploitation cost is greatly increased, the polymer viscosity loss is reduced, and the method has great significance for the development of tertiary oil recovery technology, the improvement of the production efficiency of an oil field and the reduction of the exploitation cost.
The existing methods for improving the viscosity of the polymer prepared from sewage mainly comprise the following steps: firstly, the produced water of the oil field is treated by reverse osmosis or nanofiltration membrane and the like, so that the concentration of inorganic salt ions in the produced water is reduced, and the viscosity of the polymer is improved; complexing ferrous ions, calcium ions, magnesium ions and other metal ions which have great influence on the viscosity of the polymer through a complexing agent so as to reduce the influence on the polymer and reduce the viscosity loss of the polymer; thirdly, removing the sulfide in the water and the viscosity loss of the polymer caused by bacteria by oxidation methods such as aeration oxidation, photooxidation and the like; fourthly, the viscosity of the polymer is increased by removing the dissolved oxygen in the produced water. The above method cannot be widely used due to the factors such as the use cost, the limitation of operability and the use range, and the like, and the research on a new method for controlling the viscosity loss of the polymer is of great significance.
Disclosure of Invention
The invention aims to solve the problems of unstable polymer viscosity and large loss in the process of injecting the conventional prepared polymer into the underground, and further provides an oilfield polymer viscosity loss inhibitor and a using method thereof.
The oilfield polymer viscosity loss inhibitor is prepared from 5-20% of nitrite, 0.1% of sodium hydroxide, 0.01-0.03% of nutrient elements, 0.1-0.5% of synergistic inhibitor and the balance of water by mass percentage.
The application method of the oilfield polymer viscosity loss inhibitor specifically comprises the following steps:
firstly, adding an oilfield polymer viscosity loss inhibitor into a dosing tank, and storing the oilfield polymer viscosity loss inhibitor into the dosing tank after stirring by a stirrer;
pumping high-concentration inhibitor mother liquor into a polymer-containing oilfield produced water delivery pipe through a dosing pump, and adjusting the flow rate of the dosing pump to enable the concentration of the polymer viscosity loss inhibitor in oilfield produced water to be 10-100 mg/L to obtain oilfield produced water to be used;
and thirdly, using the produced water of the oil field to be used for preparing polymer mother liquor and diluting polymer, and then using the produced water for oil exploitation.
The invention has the beneficial effects that:
the invention can effectively reduce the bacterial content and the ferrous ion concentration in the prepared polymer, greatly reduce the viscosity loss of the polymer in the process from preparation to injection into the ground, improve the stability of the polymer viscosity, effectively reduce the production input cost and simultaneously avoid the problem of produced water treatment caused by adding excessive polymer. The medicament is added and used by automatic medicament adding equipment, the operation is simple, the efficiency is high, the convenience is high, and the operation cost is low.
The used medicament is non-toxic and pollution-free, is easy to obtain, has low cost, can be decomposed and utilized under proper conditions, and does not produce secondary pollution.
The invention is suitable for preparing or diluting polymer oil field ground system with clear water and sewage and polymer viscosity loss problem caused by bacteria metabolism activity.
Detailed Description
The first embodiment is as follows: the oilfield polymer viscosity loss inhibitor is prepared from 5-20% of nitrite, 0.1% of sodium hydroxide, 0.01-0.03% of nutrient elements, 0.1-0.5% of synergistic inhibitor and the balance of water by mass percent.
The second embodiment is as follows: the first difference between the present embodiment and the specific embodiment is: the nutrient elements are a mixture of sodium nitrate, potassium nitrate and sodium nitrite; wherein the volume ratio of the sodium nitrate to the potassium nitrate to the sodium nitrite is 0.5:0.5: 1. The rest is the same as the first embodiment.
The third concrete implementation mode: the present embodiment differs from the first or second embodiment in that: the synergistic inhibitor is a mixture of ammonium molybdate and sodium molybdate; wherein the volume ratio of the ammonium molybdate to the sodium molybdate is 1: 1. The other is the same as in the first or second embodiment.
The fourth concrete implementation mode: the difference between this embodiment mode and one of the first to third embodiment modes is: the water is oily sewage reaching the reinjection standard, polymer-containing sewage reaching the reinjection standard or clear water. The others are the same as in one of the first to third embodiments.
The fifth concrete implementation mode: the application method of the oilfield polymer viscosity loss inhibitor in the embodiment specifically comprises the following steps:
firstly, adding an oilfield polymer viscosity loss inhibitor into a dosing tank, and storing the oilfield polymer viscosity loss inhibitor into the dosing tank after stirring by a stirrer;
pumping high-concentration inhibitor mother liquor into a polymer-containing oilfield produced water delivery pipe through a dosing pump, and adjusting the flow rate of the dosing pump to enable the concentration of the polymer viscosity loss inhibitor in oilfield produced water to be 10-100 mg/L to obtain oilfield produced water to be used;
and thirdly, using the produced water of the oil field to be used for preparing polymer mother liquor and diluting polymer, and then using the produced water for oil exploitation.
The embodiment reduces the viscosity of the polymer prepared from sewage and the loss of the polymer in the injection process by removing ferrous ions in water and inhibiting the activity of sulfate reducing bacteria.
According to the embodiment, the composite polymer viscosity loss inhibitor is used for reducing the metabolic activity of bacteria and reducing the degradation of the bacteria to the polymer, so that the number of bacteria in a coordination system is reduced and the viscosity loss is reduced. Meanwhile, the problems of ferrous ion concentration caused by bacteria or electrochemical corrosion of pipelines, polymer viscosity loss caused by ferrous ions and the like are reduced, and the harm and economic loss caused by polymer preparation and oil field production are greatly reduced.
The sixth specific implementation mode: the fifth embodiment is different from the fifth embodiment in that: and step two, the dosing pump is a metering pump or a peristaltic pump. The rest is the same as the fifth embodiment.
The seventh embodiment: the fifth or sixth embodiment is different from the fifth or sixth embodiment in that: and in the second step, the flow rate of the dosing pump is adjusted to enable the concentration of the oilfield polymer viscosity loss inhibitor in oilfield produced water to be 50 mg/L. The other is the same as the fifth or sixth embodiment.
The specific implementation mode is eight: the difference between this embodiment mode and one of the fifth to seventh embodiment modes is that: and in the third step, the polymer in the polymer mother liquor is anionic polyacrylamide with the molecular weight of 700-2000 ten thousand. The rest is the same as one of the fifth to seventh embodiments.
The effects of the present invention were verified by the following tests:
the first embodiment is as follows: the use method of the oilfield polymer viscosity loss inhibitor specifically comprises the following steps:
weighing 15% of nitrite, 0.1% of sodium hydroxide, 0.01% of nutrient elements, 0.2% of synergistic inhibitor and the balance of oilfield produced water by mass percent, adding the nitrite, the sodium hydroxide, the nutrient elements and the balance of oilfield produced water into a dosing tank, preparing 1L of oilfield polymer viscosity loss inhibitor mother liquor, and storing the oilfield polymer viscosity loss inhibitor mother liquor in the dosing tank; the oilfield produced water is oily sewage meeting the reinjection standard;
secondly, taking 1L of oilfield produced water, adding the prepared oilfield polymer viscosity loss inhibitor mother liquor, and adjusting the concentration of the oilfield polymer viscosity loss inhibitor in the oilfield produced water to be 50mg/L to obtain the inhibitor mother liquor to be used; taking 400mL of anion polyacrylamide solution mother liquor with the concentration of 5000mg/L prepared by adding anion polyacrylamide, stirring for 4 hours by using a stirrer, wherein the rotating speed of the stirrer is 400r/min, then taking two anion polyacrylamide solution mother liquor with the concentration of 5000mg/L and adopting inhibitor mother liquor to be used to respectively dilute the two anion polyacrylamide solution mother liquor into anion polyacrylamide solutions with the concentrations of 700mg/L and 1000mg/L respectively 150mL, using oil field produced water without bactericide and inhibitor to prepare the same anion polyacrylamide solution without bactericide and inhibitor according to the flow as blank control, and recording the polymer viscosity (mPas) of 0h, 12h and 24h, wherein the results are shown in Table 1.
TABLE 1 Effect of Polymer viscosity loss inhibitors on Polymer viscosity
As can be seen from Table 1, the polymer viscosity loss was small at 24 hours for the presence of the inhibitor in the 700mg/L and 1000mg/L polymer solutions, and when the inhibitor was not used, the 24-hour viscosity loss rates were 13.7% and 10.0% for the 700mg/L and 1000mg/L polymer solutions, respectively, and after the use of the polymer viscosity loss inhibitor, the 24-hour viscosity loss rates were reduced to 1.1% and 0.8% for the 700mg/L and 1000mg/L polymer solutions, respectively.
Example two:
an on-site application experiment is carried out at a polymer injection station of a certain oil field, mother liquor of the inhibitor to be used, which is prepared in the mode of the second step of the embodiment, is added to a water inlet pipeline of the polymer injection station through a peristaltic pump, the concentration of the inhibitor is adjusted to be 0mg/L, 25mg/L, 50mg/L, 75mg/L and 100mg/L respectively, a filter is taken to process the polymer to detect the viscosity of the polymer, the produced water of the oil field, which is not added with the inhibitor, is used for preparing the polymer with the same concentration as a blank control, the viscosity loss rate is calculated, the result is shown in table 2, and the contents of Sulfate Reducing Bacteria (SRB), saprophytic bacteria (TGB), iron bacteria (FB), sulfide and ferrous ions in.
Table 2 polymer dosing station filter viscosity test
As is clear from Table 2, the average viscosity loss rate of the polymer at the filter was 24.2% when no inhibitor was added, and the viscosity loss rates of the polymers were less than 1.3% at inhibitor concentrations of 25mg/L, 50mg/L, 75mg/L and 100mg/L, respectively, and the effect of reducing the viscosity loss of the polymer was significant.
TABLE 3 Polymer solution quality test table for polymer injection station filter
As can be seen from table 3, the addition of the inhibitor can reduce the content of sulfate-reducing bacteria, saprophytic bacteria, iron bacteria, sulfide and ferrous ions in the polymer solution, and the content of sulfate-reducing bacteria, saprophytic bacteria, iron bacteria, sulfide and ferrous ions decreases with the increase of the concentration of the inhibitor.
Claims (8)
1. The oilfield polymer viscosity loss inhibitor is characterized by being prepared from 5-20% of nitrite, 0.1% of sodium hydroxide, 0.01-0.03% of nutrient elements, 0.1-0.5% of synergistic inhibitor and the balance of water by mass percent.
2. The oilfield polymer viscosity loss inhibitor of claim 1, wherein the nutrient is a mixture of sodium nitrate, potassium nitrate, and sodium nitrite; wherein the volume ratio of the sodium nitrate to the potassium nitrate to the sodium nitrite is 0.5:0.5: 1.
3. The oilfield polymer viscosity loss inhibitor of claim 1, wherein the synergistic inhibitor is a mixture of ammonia molybdate and sodium molybdate; wherein the volume ratio of the ammonium molybdate to the sodium molybdate is 1: 1.
4. The oilfield polymer viscosity loss inhibitor of claim 1, wherein the water is oily wastewater meeting reinjection criteria, polymer-containing wastewater meeting reinjection criteria, or clear water.
5. The method of using the oilfield polymer viscosity loss inhibitor of claim 1, wherein the oilfield polymer viscosity loss inhibitor is applied by the steps of:
firstly, adding an oilfield polymer viscosity loss inhibitor into a dosing tank, and storing the oilfield polymer viscosity loss inhibitor into the dosing tank after stirring by a stirrer;
pumping high-concentration inhibitor mother liquor into a polymer-containing oilfield produced water delivery pipe through a dosing pump, and adjusting the flow rate of the dosing pump to enable the concentration of the polymer viscosity loss inhibitor in oilfield produced water to be 10-100 mg/L to obtain oilfield produced water to be used;
and thirdly, using the produced water of the oil field to be used for preparing polymer mother liquor and diluting polymer, and then using the produced water for oil exploitation.
6. The method of using the oilfield polymer viscosity loss inhibitor of claim 5, wherein the dosing pump of step two is a metering pump or a peristaltic pump.
7. The method of claim 5, wherein the flow rate of the chemical feed pump is adjusted in step two to achieve a concentration of 50mg/L of the oilfield polymer viscosity loss inhibitor in oilfield produced water.
8. The use method of the oilfield polymer viscosity loss inhibitor according to claim 5, wherein the polymer in the polymer mother liquor in the third step is anionic polyacrylamide with the molecular weight of 700-2000 ten thousand.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010546691.0A CN111662699A (en) | 2020-06-16 | 2020-06-16 | Oilfield polymer viscosity loss inhibitor and application method thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010546691.0A CN111662699A (en) | 2020-06-16 | 2020-06-16 | Oilfield polymer viscosity loss inhibitor and application method thereof |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN111662699A true CN111662699A (en) | 2020-09-15 |
Family
ID=72387942
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010546691.0A Pending CN111662699A (en) | 2020-06-16 | 2020-06-16 | Oilfield polymer viscosity loss inhibitor and application method thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111662699A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112408711A (en) * | 2020-11-23 | 2021-02-26 | 中国石油化工股份有限公司 | Treatment method of oilfield chemical flooding produced water |
Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP3178903A1 (en) * | 2015-12-10 | 2017-06-14 | Wintershall Holding GmbH | Composition and method for inhibition of srb in meor |
| CN108251090A (en) * | 2016-12-29 | 2018-07-06 | 黑龙江吉纳森生物工程股份有限公司 | A kind of poly- drive viscosity loss inhibitor |
| CN108728072A (en) * | 2017-04-21 | 2018-11-02 | 中国石油化工股份有限公司 | A kind of oilfield polymer solution viscosity protective agent and its application |
-
2020
- 2020-06-16 CN CN202010546691.0A patent/CN111662699A/en active Pending
Patent Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP3178903A1 (en) * | 2015-12-10 | 2017-06-14 | Wintershall Holding GmbH | Composition and method for inhibition of srb in meor |
| CN108251090A (en) * | 2016-12-29 | 2018-07-06 | 黑龙江吉纳森生物工程股份有限公司 | A kind of poly- drive viscosity loss inhibitor |
| CN108728072A (en) * | 2017-04-21 | 2018-11-02 | 中国石油化工股份有限公司 | A kind of oilfield polymer solution viscosity protective agent and its application |
Non-Patent Citations (1)
| Title |
|---|
| 尹子超等: ""油田废水的硫化物控制技术"", 《净水技术》 * |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112408711A (en) * | 2020-11-23 | 2021-02-26 | 中国石油化工股份有限公司 | Treatment method of oilfield chemical flooding produced water |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN100465267C (en) | Microorganism for controlling harm of oil field sulfate reductive bacterium and application thereof | |
| CN103534330A (en) | Systems and methods of microbial enhanced oil recovery | |
| CN103787530A (en) | Method and system for handling fracture flowback liquid | |
| CN104449648A (en) | Drag reducer for slickwater fracturing on unconventional oil and gas reservoirs and preparation method of drag reducer | |
| CN105419763A (en) | Casing annulus protection fluid and preparation method thereof | |
| WO2021254098A1 (en) | Method for reducing viscosity loss by means of regulating and controlling microbial community structure composition in polymer prepared from water produced by oilfield | |
| CN111662699A (en) | Oilfield polymer viscosity loss inhibitor and application method thereof | |
| CN107973418B (en) | Composite corrosion and scale inhibitor, corrosion and scale inhibition method for oil field water and oil extraction method | |
| CN103224776A (en) | Oil field flooding stratum protective agent and preparation method and application thereof | |
| CN205133364U (en) | Shale atmospheric pressure splits and returns flowing back degree of depth processing system | |
| CN111286313A (en) | Barium-strontium sulfate scale biological descaling liquid and descaling method thereof | |
| CN101229943A (en) | Method for treating hydrogen sulfide by intensifying activity of indigenous microorganism | |
| CN109209268A (en) | The method that drain is returned in acidification is handled using reproducibility iron powder | |
| CN111676006B (en) | Composite medicament for changing metabolic mode of sulfate reducing bacteria and use method thereof | |
| CN102774897B (en) | Treatment method of polymer flooding and binary combination flooding-SP-sewage | |
| CN102442737A (en) | Method for treating low-temperature oily wastewater with strong oxidant | |
| CN111662691A (en) | Method for reducing viscosity loss of polymer prepared from oilfield produced water through complexing agent | |
| CN110563194B (en) | Pretreatment agent and pretreatment method for fracturing flow-back fluid for preparing drilling fluid | |
| CN111574985A (en) | Method for improving viscosity of polymer mother liquor by reducing content of dissolved oxygen in polymer preparation process | |
| CN109133559B (en) | Agent and method for reducing chemical oxygen demand of waste sulfonated mud for drilling | |
| CN111517482A (en) | Method for controlling sulfide in oil field sewage | |
| CN102477855B (en) | Method for improving oil displacement efficiency of reinjection after hypotonic oil deposit high salt produced water disposal | |
| CN102167450A (en) | Special corrosion and scale inhibitor for oilfield reinjection water and preparation method of corrosion and scale inhibitor | |
| CN110872159B (en) | Oil field polymer flooding full sewage polymerization treatment process | |
| CN107973420B (en) | Composite corrosion and scale inhibitor, corrosion and scale inhibition method for oil field water and oil extraction method |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| WD01 | Invention patent application deemed withdrawn after publication | ||
| WD01 | Invention patent application deemed withdrawn after publication |
Application publication date: 20200915 |