CN111499040A - Oil field fracturing flowback fluid reinjection treatment method - Google Patents
Oil field fracturing flowback fluid reinjection treatment method Download PDFInfo
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- CN111499040A CN111499040A CN202010338997.7A CN202010338997A CN111499040A CN 111499040 A CN111499040 A CN 111499040A CN 202010338997 A CN202010338997 A CN 202010338997A CN 111499040 A CN111499040 A CN 111499040A
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- 239000012530 fluid Substances 0.000 title claims abstract description 59
- 238000011282 treatment Methods 0.000 title claims abstract description 49
- 238000000034 method Methods 0.000 title claims abstract description 32
- 238000001914 filtration Methods 0.000 claims abstract description 82
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 67
- 238000005260 corrosion Methods 0.000 claims abstract description 22
- 230000007797 corrosion Effects 0.000 claims abstract description 22
- 239000007788 liquid Substances 0.000 claims abstract description 20
- 230000000844 anti-bacterial effect Effects 0.000 claims abstract description 16
- 239000003899 bactericide agent Substances 0.000 claims abstract description 16
- 239000000701 coagulant Substances 0.000 claims abstract description 14
- 238000003756 stirring Methods 0.000 claims abstract description 14
- 230000005764 inhibitory process Effects 0.000 claims abstract description 10
- 238000000926 separation method Methods 0.000 claims abstract description 10
- 238000004062 sedimentation Methods 0.000 claims abstract description 8
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 7
- 238000005189 flocculation Methods 0.000 claims abstract description 6
- 239000006228 supernatant Substances 0.000 claims abstract description 6
- 230000016615 flocculation Effects 0.000 claims abstract description 3
- 239000000243 solution Substances 0.000 claims description 18
- 239000000203 mixture Substances 0.000 claims description 11
- 239000011259 mixed solution Substances 0.000 claims description 7
- QAOWNCQODCNURD-UHFFFAOYSA-N Sulfuric acid Chemical compound OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 claims description 6
- 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 5
- MHAJPDPJQMAIIY-UHFFFAOYSA-N Hydrogen peroxide Chemical compound OO MHAJPDPJQMAIIY-UHFFFAOYSA-N 0.000 claims description 5
- 125000000129 anionic group Chemical group 0.000 claims description 5
- 229910000361 cobalt sulfate Inorganic materials 0.000 claims description 5
- KTVIXTQDYHMGHF-UHFFFAOYSA-L cobalt(2+) sulfate Chemical compound [Co+2].[O-]S([O-])(=O)=O KTVIXTQDYHMGHF-UHFFFAOYSA-L 0.000 claims description 5
- 239000011702 manganese sulphate Substances 0.000 claims description 5
- SQQMAOCOWKFBNP-UHFFFAOYSA-L manganese(II) sulfate Chemical compound [Mn+2].[O-]S([O-])(=O)=O SQQMAOCOWKFBNP-UHFFFAOYSA-L 0.000 claims description 5
- 229920002401 polyacrylamide Polymers 0.000 claims description 5
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 4
- 239000005708 Sodium hypochlorite Substances 0.000 claims description 4
- VSCWAEJMTAWNJL-UHFFFAOYSA-K aluminium trichloride Chemical compound Cl[Al](Cl)Cl VSCWAEJMTAWNJL-UHFFFAOYSA-K 0.000 claims description 4
- 229940044175 cobalt sulfate Drugs 0.000 claims description 4
- 239000003112 inhibitor Substances 0.000 claims description 4
- 229940099596 manganese sulfate Drugs 0.000 claims description 4
- 235000007079 manganese sulphate Nutrition 0.000 claims description 4
- SUKJFIGYRHOWBL-UHFFFAOYSA-N sodium hypochlorite Chemical compound [Na+].Cl[O-] SUKJFIGYRHOWBL-UHFFFAOYSA-N 0.000 claims description 4
- KHSLHYAUZSPBIU-UHFFFAOYSA-M benzododecinium bromide Chemical compound [Br-].CCCCCCCCCCCC[N+](C)(C)CC1=CC=CC=C1 KHSLHYAUZSPBIU-UHFFFAOYSA-M 0.000 claims description 3
- -1 imidazoline quaternary ammonium salt Chemical class 0.000 claims description 3
- KBTJYNAFUYTSNN-UHFFFAOYSA-N [Na].OO Chemical compound [Na].OO KBTJYNAFUYTSNN-UHFFFAOYSA-N 0.000 claims description 2
- 239000003054 catalyst Substances 0.000 claims description 2
- 230000003197 catalytic effect Effects 0.000 claims description 2
- 229910000365 copper sulfate Inorganic materials 0.000 claims description 2
- 229960000355 copper sulfate Drugs 0.000 claims description 2
- ARUVKPQLZAKDPS-UHFFFAOYSA-L copper(II) sulfate Chemical compound [Cu+2].[O-][S+2]([O-])([O-])[O-] ARUVKPQLZAKDPS-UHFFFAOYSA-L 0.000 claims description 2
- QWPPOHNGKGFGJK-UHFFFAOYSA-N hypochlorous acid Chemical compound ClO QWPPOHNGKGFGJK-UHFFFAOYSA-N 0.000 claims description 2
- RMAQACBXLXPBSY-UHFFFAOYSA-N silicic acid Chemical compound O[Si](O)(O)O RMAQACBXLXPBSY-UHFFFAOYSA-N 0.000 claims description 2
- 235000012239 silicon dioxide Nutrition 0.000 claims description 2
- 238000005345 coagulation Methods 0.000 abstract description 2
- 230000015271 coagulation Effects 0.000 abstract description 2
- 238000000746 purification Methods 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 54
- 238000002347 injection Methods 0.000 description 17
- 239000007924 injection Substances 0.000 description 17
- 238000005086 pumping Methods 0.000 description 14
- 239000000499 gel Substances 0.000 description 11
- 230000035699 permeability Effects 0.000 description 11
- 238000011161 development Methods 0.000 description 10
- 230000000694 effects Effects 0.000 description 10
- 239000002245 particle Substances 0.000 description 8
- 241000894006 Bacteria Species 0.000 description 7
- 241000295146 Gallionellaceae Species 0.000 description 7
- 239000010963 304 stainless steel Substances 0.000 description 6
- 229910000589 SAE 304 stainless steel Inorganic materials 0.000 description 6
- 239000007787 solid Substances 0.000 description 6
- 230000002401 inhibitory effect Effects 0.000 description 5
- 229920000742 Cotton Polymers 0.000 description 4
- 239000000463 material Substances 0.000 description 4
- 239000003208 petroleum Substances 0.000 description 4
- 238000003908 quality control method Methods 0.000 description 4
- 229910021578 Iron(III) chloride Inorganic materials 0.000 description 3
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 3
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 3
- 238000004458 analytical method Methods 0.000 description 3
- RBTARNINKXHZNM-UHFFFAOYSA-K iron trichloride Chemical compound Cl[Fe](Cl)Cl RBTARNINKXHZNM-UHFFFAOYSA-K 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- 239000011435 rock Substances 0.000 description 3
- 229910000975 Carbon steel Inorganic materials 0.000 description 2
- ZRALSGWEFCBTJO-UHFFFAOYSA-N Guanidine Chemical compound NC(N)=N ZRALSGWEFCBTJO-UHFFFAOYSA-N 0.000 description 2
- 241000758789 Juglans Species 0.000 description 2
- 235000009496 Juglans regia Nutrition 0.000 description 2
- 239000006004 Quartz sand Substances 0.000 description 2
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 2
- 229910052782 aluminium Inorganic materials 0.000 description 2
- 239000010962 carbon steel Substances 0.000 description 2
- 125000004122 cyclic group Chemical group 0.000 description 2
- 239000000839 emulsion Substances 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 238000002156 mixing Methods 0.000 description 2
- 239000002332 oil field water Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 235000020234 walnut Nutrition 0.000 description 2
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 description 1
- CHJJGSNFBQVOTG-UHFFFAOYSA-N N-methyl-guanidine Natural products CNC(N)=N CHJJGSNFBQVOTG-UHFFFAOYSA-N 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 230000001580 bacterial effect Effects 0.000 description 1
- 230000033228 biological regulation Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000009388 chemical precipitation Methods 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- SWSQBOPZIKWTGO-UHFFFAOYSA-N dimethylaminoamidine Natural products CN(C)C(N)=N SWSQBOPZIKWTGO-UHFFFAOYSA-N 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000003344 environmental pollutant Substances 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 229910001448 ferrous ion Inorganic materials 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- SZVJSHCCFOBDDC-UHFFFAOYSA-N iron(II,III) oxide Inorganic materials O=[Fe]O[Fe]O[Fe]=O SZVJSHCCFOBDDC-UHFFFAOYSA-N 0.000 description 1
- 235000015110 jellies Nutrition 0.000 description 1
- 239000008274 jelly Substances 0.000 description 1
- 239000012528 membrane Substances 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 231100000719 pollutant Toxicity 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 238000010561 standard procedure Methods 0.000 description 1
- 238000011272 standard treatment Methods 0.000 description 1
- 230000001954 sterilising effect Effects 0.000 description 1
- 238000004659 sterilization and disinfection Methods 0.000 description 1
- 239000003206 sterilizing agent Substances 0.000 description 1
- 239000011550 stock solution Substances 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F9/00—Multistage treatment of water, waste water or sewage
-
- 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
- E21B43/20—Displacing by water
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/001—Processes for the treatment of water whereby the filtration technique is of importance
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/50—Treatment of water, waste water, or sewage by addition or application of a germicide or by oligodynamic treatment
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/52—Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
- C02F1/5236—Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities using inorganic agents
- C02F1/5245—Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities using inorganic agents using basic salts, e.g. of aluminium and iron
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/52—Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
- C02F1/54—Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities using organic material
- C02F1/56—Macromolecular compounds
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/66—Treatment of water, waste water, or sewage by neutralisation; pH adjustment
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F1/00—Treatment of water, waste water, or sewage
- C02F1/72—Treatment of water, waste water, or sewage by oxidation
- C02F1/725—Treatment of water, waste water, or sewage by oxidation by catalytic oxidation
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F2103/00—Nature of the water, waste water, sewage or sludge to be treated
- C02F2103/10—Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F2303/00—Specific treatment goals
- C02F2303/04—Disinfection
-
- C—CHEMISTRY; METALLURGY
- C02—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F—TREATMENT OF WATER, WASTE WATER, SEWAGE, OR SLUDGE
- C02F2303/00—Specific treatment goals
- C02F2303/08—Corrosion inhibition
Landscapes
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Environmental & Geological Engineering (AREA)
- Mining & Mineral Resources (AREA)
- Water Supply & Treatment (AREA)
- Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Hydrology & Water Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Separation Of Suspended Particles By Flocculating Agents (AREA)
Abstract
The invention belongs to the technical field of oil field fracturing flow-back fluid treatment, and particularly relates to a method for reinjection treatment of oil field fracturing flow-back fluid. The method specifically comprises the following steps: 1) gel breaking and oil removing treatment: adding a pH regulator and a gel breaking viscosity reducer into the oil field fracturing flow-back fluid, and stirring to uniformly mix; 2) flocculation and sedimentation treatment: adding a coagulant and a coagulant aid into the mixed liquid obtained in the step 1), stirring to uniformly mix, and then settling and carrying out solid-liquid separation; 3) controlling the water quality: filtering the supernatant fluid after the sedimentation in the step 2); during or after filtration, the corrosion and scale inhibition bactericide is added to realize stable water quality reaching the standard. According to the invention, by combining the measures of gel breaking and viscosity reduction, deoiling treatment, coagulation and sedimentation treatment, filtering treatment, water quality stability control and the like, the fracturing flow-back fluid meets the reinjection requirement of the low-permeability oilfield while being subjected to purification treatment, so that the problem that the water quality does not reach the standard after the fracturing flow-back fluid of the low-permeability oilfield is treated in the prior art is solved.
Description
Technical Field
The invention belongs to the technical field of oil field fracturing flow-back fluid treatment, and particularly relates to a method for reinjection treatment of oil field fracturing flow-back fluid.
Background
The well entry fracturing fluid used in the large-scale hydraulic fracturing operation of the horizontal well for developing the low-permeability oilfield compact oil mainly takes guanidine gum jelly as a main component, when open-flow fracturing operation is carried out after the fracturing operation, the oil content in the flowback fluid waste liquid is high, the chemical composition is complex, the viscosity is high, the content of soluble inorganic matters, organic matters, suspended matters, bacteria and other pollutants is high, and the low-permeability oilfield compact oil is a stable emulsion. The fracturing flow-back fluid treatment process is complex, and if the fracturing flow-back fluid is not properly treated, the subsequent development progress of the compact oil is directly influenced.
The research result shows that after the treatment of the flowback liquid, the flowback liquid reaches the water quality index of the great-quality oil field united station reinjection water (the contents of suspended matters and oils meet the double 20 standard of less than or equal to 20 mg/L), the process is pulled nearby to the united station for reinjection disposal, but the method is only suitable for the treatment of the stratum reinjection water with the average permeability of the oil layer of more than 0.6 mu m2Namely the water quality C3 standard of water injection in the development of high-permeability oil reservoirs, is not suitable for the average permeability of oil layers less than 0.1 mu m2Namely, the water quality of water injected for the development of low-permeability oil fields is in the A1 standard (the C3 standard is that suspended matters are less than or equal to 10 mg/L and petroleum are less than or equal to 20 mg/L and the A1 standard is that suspended matters are less than or equal to 3 mg/L, the median of the particle diameters of the suspended matters is less than or equal to 1 mu m and the petroleum is less than or equal to 5 mg/L). the patent CN21201220678312.4 discloses a dense oil reservoir mixed water fracturing flow-back fluid treatment device, and provides a treatment device integrated by a sand settling oil separation, chemical precipitation, filtration and water quality regulation combined treatment process.
For a low-permeability oil field, the fracturing flowback fluid of a compact oil development horizontal well mainly faces the following three problems if the fracturing flowback fluid is required to be reinjected to reach the standard: first, the development of low-permeability oil field compact oil has high requirements on the quality of water injected. In the process of developing compact oil, the reinjection reservoir has the characteristics of low permeability and strong water sensitivity, so that the requirement on water quality indexes is higher, and the difficulty in standard treatment of suspended matters and oil content is higher. The current fracturing flow-back fluid treatment technology is difficult to reach the corresponding standard. Secondly, the components of the fracturing flow-back fluid are complex, and the quality of the reinjection water can not reach the standard by using a conventional process for treatment. The dense oil fracturing flow-back fluid has high oil content, simultaneously contains a large amount of suspended matters and bacteria, and has a high COD value. A large amount of clay and rock debris particles exist in the water, the water is expressed as emulsion, the stability is extremely high, and the water is difficult to be completely degraded by adopting a conventional process, so that the requirement of reinjection water quality cannot be met. And thirdly, the compatibility of the flowback liquid and the injected water is poor, and the reservoir is easily damaged. Relevant researches show that no matter what proportion is used for mixing injected water and fracturing flowback fluid, the permeability loss rate of the mixture to a formation core is kept to be more than 50% and can reach 72.89% at most, and reducing substances (mainly comprising ferrous ions, organic matters and the like) and polymers in the flowback fluid are main factors causing permeability damage.
Disclosure of Invention
In order to solve the technical problems, the invention aims to provide a method for treating the fracturing flow-back fluid of the horizontal well of the low-permeability oilfield by reinjecting the fracturing flow-back fluid, which combines the means of gel breaking, viscosity reduction, oil removal, coagulation and sedimentation treatment, filtration treatment, stable water quality control and the like, so that the fracturing flow-back fluid can meet the reinjection requirement of the low-permeability oilfield while being subjected to purification treatment, and the problem that the water quality of the fracturing flow-back fluid of the low-permeability oilfield cannot reach the standard after treatment in the prior art is solved.
In order to achieve the technical purpose, the invention adopts the following technical scheme:
the reinjection treatment method of the oilfield fracturing flow-back fluid is characterized by comprising the following steps:
1) gel breaking and oil removing treatment: adding a pH regulator and a gel breaking viscosity reducer into the oil field fracturing flow-back fluid, and stirring to uniformly mix;
2) flocculation and sedimentation treatment: adding a coagulant and a coagulant aid into the mixed liquid obtained in the step 1), stirring to uniformly mix, and then settling and carrying out solid-liquid separation;
3) controlling the water quality: filtering the supernatant fluid after the sedimentation in the step 2); during or after filtration, the corrosion and scale inhibition bactericide is added to realize stable water quality reaching the standard.
Preferably, the gel breaking viscosity reducer used in the step 1) consists of a viscosity reducing component and a catalytic component, wherein the usage amount of the viscosity reducing component is 0.8-2.0L/m3The usage amount of the catalyst component is 1.0-2L/m3；
The viscosity reducer comprises 10-30% by mass of one or more than two mixed solutions in any proportion of hypochlorous acid, sodium hypochlorite, hydrogen peroxide and sodium hydrogen peroxide; the viscosity reducing component is one or a mixture of more than two of cobalt sulfate, manganese sulfate and copper sulfate with the mass fraction of 10-30% in any proportion.
Preferably, the pH regulator used in the step 1) is dilute hydrochloric acid or dilute sulfuric acid with the mass fraction of 5-20%, and the addition amount of the pH regulator is 3.2-4.0L/m3。
Preferably, the addition amount of the coagulant in the step 2) is 1.0-1.5L/m3The addition amount of coagulant aid is 5-20L/m3；
The coagulant is a polymeric silicic acid ferric aluminum chloride solution with the mass fraction of 10-20%; the coagulant aid is an anionic polyacrylamide solution with the mass fraction of 0.001-0.5%.
Preferably, the filtration in step 3) comprises coarse filtration and fine filtration; the filtration precision of rough filtration is 25-50 μm; the filtering precision of the fine filtration is 1-5 μm.
Preferably, the corrosion and scale inhibiting bactericide in the step 3) is a solution with the mass fraction of 1-10%, and the addition amount is 0.1-1.5L/m3(ii) a The effective components of the corrosion and scale inhibition bactericide consist of a corrosion inhibitor component and a bactericide component.
Preferably, the effective components of the corrosion and scale inhibition bactericide are prepared from imidazoline quaternary ammonium salt, hydroxy ethylidene diphosphonic acid (HEDP) and dodecyl dimethyl benzyl ammonium bromide according to the mass ratio of 5-15: 1-3: 10-50.
The invention provides a method for treating fracturing flow-back fluid reinjection of low-permeability oilfield compact oil development to reach the standard, which purifies the fracturing flow-back fluid of the oilfield to the reinjection water standard by a method combining gel breaking, viscosity reduction, multi-stage filtration and reinjection water quality control, particularly meets the requirement of the A1 standard of the low-permeability or ultra-low-permeability oilfield water injection industry, realizes the cyclic utilization of the fracturing flow-back fluid and the reinjection water of the low-permeability oilfield, and is an economic and efficient fracturing flow-back fluid reinjection treatment method.
The specific implementation mode is as follows:
the present invention will be described in further detail with reference to specific examples. The reagents and materials used in the present invention are either commonly available or available to one skilled in the art through published routes.
When the treatment effect of the fracturing flowback fluid of the tight oil horizontal well of the low-permeability oilfield is evaluated, reference is made to 'recommended index and analysis method for water injection quality of clastic rock oil deposit (SY/T5329-2012)' bactericide for oil field (Q/SY49-2007) 'performance index and evaluation method of corrosion inhibitor for water treatment of oil field extraction (SY/T5273-2014)' technical requirement of corrosion and scale inhibitor for water treatment of oil field (Q/SY126-2007) 'and' analysis method for water of oil field '(SY/T5523-2016)'.
Example 1
Get the dense oil horizontal well of a certain low-permeability oil field in the west bigFracturing flowback fluid 30m generated by hydraulic fracturing operation3Continuously pumping the mixture into a gel breaking and viscosity reducing reactor, and continuously adding a dilute hydrochloric acid solution with the mass fraction of 10 percent of 3.2L/m under the stirring of medium speed (150r/min)3Mixing, and sequentially adding sodium hypochlorite solution 1.6L/m with mass fraction of 10%3And a 20 mass percent mixed solution of cobalt sulfate and manganese sulfate (the mass ratio of cobalt sulfate to manganese sulfate is 2:1) 1.0L/m3Stirring to mix evenly;
pumping the mixed solution into a coagulation-flocculation reactor, and sequentially and continuously adding a polysilicate aluminum ferric chloride solution with the mass fraction of 15% under the stirring at a low speed (75r/min) of 1.0L/m3And 0.1 percent of anionic polyacrylamide aqueous solution 10L/m3Pumping the mixed liquid into a two-stage settling separator for solid-liquid separation;
and after solid-liquid separation, pumping the supernatant into a filter tank for filtering. In order to ensure the filtering effect, the filtering process comprises two stages of coarse filtering and two stages of fine filtering. The coarse filtration process uses a bag-type coarse filtration tank which is composed of a 304 stainless steel filtration shell, a support filtration basket and a filtration bag, and the specification and model are
The filter bag is a PPR filter bag with the specification of
The aperture of the filter bag is respectively selected to be 50 μm and 25 μm. The fine filtration process uses a filter element type fine filtration tank which consists of a 304 stainless steel filtration shell, a support filter basket and a filtration filter element and has the specification of
The filter element is a PP filter cotton core with the specification of
The filter pore diameter is 5 μm and 1 μm in sequence. Flow rate in filtration process 30m3H, controlling the pressure to be 0.3-0.4 MPa;
HK-20 corrosion-inhibiting, scale-inhibiting and sterilizing agent with mass fraction of 5% is continuously pumped into a water inlet of the primary fine filtration tankThe corrosion and scale inhibiting bactericide is prepared from imidazoline quaternary ammonium salt, hydroxyethylidene diphosphonic acid (HEDP) and dodecyl dimethyl benzyl ammonium bromide in a mass ratio of 10: 1.5: 30, and the dosage of the HK-20 corrosion and scale inhibiting bactericide is 0.6L/m3And the filtered clean water is continuously pumped into a water injection system through a booster water injection pump and enters an oil layer for water injection development.
Example 2
Taking 30m of fracturing flowback fluid generated by large-scale hydraulic fracturing operation of a low-permeability oilfield tight oil well in the west3Continuously pumping the mixture into a gel breaking and viscosity reducing reactor, and continuously adding a dilute hydrochloric acid solution with the mass fraction of 10 percent of 4.0L/m under the stirring of 150r/min3After being mixed evenly, the mixture is added with hydrogen peroxide solution with the mass fraction of 30 percent of 0.8L/m3Manganese sulfate solution with mass fraction of 20 percent of 1.5L/m3Stirring to mix evenly;
pumping the mixed solution into a coagulation-flocculation reactor, and sequentially and continuously adding a polyaluminum ferric chloride solution with the mass fraction of 15% 1.5L/m under the stirring of 75r/min3And 0.1 percent of anionic polyacrylamide solution 10L/m in mass fraction3Pumping the mixed liquid into a two-stage settling separator for solid-liquid separation;
and after solid-liquid separation, pumping the supernatant into a filter tank for filtering. In order to ensure the filtering effect, the filtering process comprises two stages of coarse filtering and two stages of fine filtering. The coarse filtration process uses a bag-type coarse filtration tank which is composed of a 304 stainless steel filtration shell, a support filtration basket and a filtration bag, and the specification and model are
The filter bag is a PPR filter bag with the specification of
The aperture of the filter bag is respectively selected to be 50 μm and 25 μm. The fine filtration process uses a filter element type fine filtration tank which consists of a 304 stainless steel filtration shell, a support filter basket and a filtration filter element and has the specification of
The filter core is PP filter cotton core and gaugeLattice is
The filter pore diameter is 5 μm and 1 μm in sequence. Flow rate in filtration process 30m3H, controlling the pressure to be 0.3-0.4 MPa;
while filtering, L HK-20 corrosion-inhibition scale-inhibition bactericide solution with the mass fraction of 5 percent is continuously pumped into the water inlet of the primary fine filtering tank, and the solution is 1.0L/m3And (4) performing stable water quality control, and pumping the filtered clear water into a water injection system to enter an oil layer for water injection development.
Example 3
Taking 30m of flowback fluid generated by large-scale fracturing operation of a low-permeability oilfield compact oil horizontal well3Continuously pumping the mixture into a gel breaking and viscosity reducing reactor, and continuously adding 3.6L/m dilute sulfuric acid with the mass fraction of 10 percent under the stirring of 150r/min3After being mixed evenly, sodium hypochlorite 2.0L/m with the mass fraction of 10 percent is added in sequence3Cobalt sulfate solution with mass fraction of 20 percent 2.0L/m3；
Pumping the mixed solution into a coagulation-flocculation reactor, and sequentially and continuously adding a polysilicate aluminum ferric chloride solution with the mass fraction of 15% at the speed of 1.2L/m under the stirring of 75r/min3And 0.1 percent of anionic polyacrylamide solution 10L/m in mass fraction3(ii) a Pumping the mixed liquid into a two-stage settling separator for solid-liquid separation;
and after solid-liquid separation, pumping the supernatant into a filter tank for filtering. In order to ensure the filtering effect, the filtering process comprises two stages of coarse filtering and two stages of fine filtering. The coarse filtration process uses a bag-type coarse filtration tank which is composed of a 304 stainless steel filtration shell, a support filtration basket and a filtration bag, and the specification and model are
The filter bag is a PPR filter bag with the specification of
The aperture of the filter bag is respectively selected to be 50 μm and 25 μm. The fine filtration process uses a filter element type fine filtration tank which consists of a 304 stainless steel filtration shell, a support filter basket and a filtration filter element and has the specification of
The filter element is a PP filter cotton core with the specification of
The filter pore diameter is 5 μm and 1 μm in sequence. Flow rate in filtration process 30m3H, controlling the pressure to be 0.3-0.4 MPa;
while filtering, L HK-20 corrosion-inhibition scale-inhibition bactericide 0.8L/m with mass fraction of 5% is continuously pumped into the water inlet of the primary fine filtering tank3And (4) performing water quality stability control treatment, and pumping the filtered clear water into a water injection system to enter an oil layer for water injection development.
According to the water injection quality standard of low permeability (average air permeability is less than or equal to 0.05mD) or ultra-low permeability oil field (average air permeability is less than or equal to 0.01mD) recommended in the 'clastic rock oil reservoir water injection quality recommendation standard and analysis method' of the China oil and gas industry standard (SY/T5329-2012), parameters such as the content of suspended solids, the median diameter of suspended particles, Sulfate Reducing Bacteria (SRB), Iron Bacteria (IB), saprophyte (TGB) and the like in the water body after the oil field fracturing flowback fluid treatment in the examples 1-3 are measured, and the measurement results are shown in the table 1;
TABLE 1 comparison of treatment effect of fracturing flowback fluid and control effect of quality of reinjection water in examples 1-3
It can be seen that after the fracturing flow-back fluid is treated by the method in examples 1-3, the suspended solid content, oil content, median diameter of suspended particles, average corrosion rate and contents of SRB, TG and IB in the water are all superior to those of the industry standard of low-permeability or ultra-low-permeability oilfield flooding, which indicates that after the treatment by the method in examples 1-3, the fracturing flow-back fluid in the oilfield completely meets the requirement of the quality of the low-permeability oilfield reinjection water, and can be injected into the stratum for water flooding development.
In order to further reveal the treatment effect of the invention on the oilfield fracturing flow-back fluid, a rigid filter tank which takes walnut shells and quartz sand as filter materials is used as a filter effect contrast, and the filter precision, flow rate and pressure control conditions of the rigid filter tank are kept consistent with those of the embodiment; respectively measuring parameters such as suspended solid content, suspended particle diameter median, SRB, TG, IB and the like in the water body, wherein specific measurement data are shown in Table 2;
TABLE 2 treatment Effect of different treatment Processes on oilfield produced fluids
The rigid filtration in the upper surface and the middle surface is to adopt walnut shells, quartz sand, magnetite ore and other rigid filter materials for filtration treatment; the elastic filtration is the filtration treatment by using the PP filter bag, the PP cotton filter element or elastic filter materials such as fiber balls, double-layer expansion filter elements, filter membranes and the like; it can be seen that after gel breaking, viscosity reduction and multi-stage rigid filtration, the suspended solid content, the median diameter value of suspended particles and the oil content in the fracturing flow-back fluid stock solution are all obviously reduced, but are still higher than the water injection quality technical standard of low-permeability or ultra-low permeability oil reservoirs in the petroleum and gas industry in China; the average corrosion rate of the corrosion inhibitor on A3 carbon steel is 0.086mm/a, slightly higher than the industrial standard and less than or equal to 0.076mm/a, and the contents of Sulfate Reducing Bacteria (SRB), Iron Bacteria (IB) and saprophytic bacteria (TGB) respectively reach 104Each/ml, 102Each/ml, 104The volume per ml is far higher than the industrial standard, and the requirement of reinjection water quality cannot be met;
after multistage elastic filtration, corrosion inhibition, scale inhibition and sterilization are adopted, the suspended solid content, the median diameter value of suspended particles and the oil content in the treatment fluid are further reduced, the average corrosion rate of the treatment fluid to A3 carbon steel is 0.026mm/a, sulfate reducing bacteria, iron bacteria and saprophytic bacteria can not be detected, the treatment fluid completely meets the technical standard of water injection quality of low-permeability or ultra-low permeability oil fields, and the water injection requirement of the oil fields can be completely met.
The results show that the traditional gel breaking and viscosity reduction-multistage rigid filtration method can reduce the petroleum content and the solid particle content in the produced liquid of the oil field, but has no obvious effect on the average corrosion rate and the bacterial content of the water body, and can not meet the water injection requirement of the oil field, especially the low-permeability oil field; the method combining gel breaking and viscosity reduction, multistage elastic filtration and reinjection water quality control can purify the fracturing flow-back fluid of the oil field to the reinjection water standard, particularly meets the requirement of the hypotonic or ultra-hypotonic oil field water injection A1 standard, realizes the cyclic utilization of the fracturing flow-back fluid of the hypotonic oil field and is an economic and efficient fracturing flow-back fluid reinjection treatment method.
Claims (7)
1. The reinjection treatment method of the oilfield fracturing flow-back fluid is characterized by comprising the following steps:
1) gel breaking and oil removing treatment: adding a pH regulator and a gel breaking viscosity reducer into the oil field fracturing flow-back fluid, and stirring to uniformly mix;
2) flocculation and sedimentation treatment: adding a coagulant and a coagulant aid into the mixed liquid obtained in the step 1), stirring to uniformly mix, and then settling and carrying out solid-liquid separation;
3) controlling the water quality: filtering the supernatant fluid after the sedimentation in the step 2); during or after filtration, the corrosion and scale inhibition bactericide is added to realize stable water quality reaching the standard.
2. The method for treating the oilfield fracturing flow-back fluid by reinjection as claimed in claim 1, wherein the gel breaking viscosity reducer used in the step 1) comprises a viscosity reducing component and a catalytic component, and the usage amount of the viscosity reducing component is 0.8-2.0L/m3The usage amount of the catalyst component is 1.0-2L/m3；
The viscosity reducer comprises 10-30% by mass of one or more than two mixed solutions in any proportion of hypochlorous acid, sodium hypochlorite, hydrogen peroxide and sodium hydrogen peroxide; the viscosity reducing component is one or more than two mixed solutions of cobalt sulfate, manganese sulfate and copper sulfate with the mass fraction of 10-30% in any proportion.
3. The method for treating the oilfield fracturing flow-back fluid by reinjection as defined in claim 1, wherein the pH regulator used in the step 1) is dilute hydrochloric acid or dilute sulfuric acid with a mass fraction of 5-20%, and the addition amount of the pH regulator is 3.2-4.0L/m3。
4. The method for treating the oilfield fracturing flow-back fluid in the claim 1, wherein the addition amount of the coagulant in the step 2) is 1.0-1.5L/m3The addition amount of coagulant aid is 5-20L/m3；
The coagulant is a polymeric silicic acid ferric aluminum chloride solution with the mass fraction of 10-20%; the coagulant aid is an anionic polyacrylamide solution with the mass fraction of 0.001-0.5%.
5. The oilfield frac flowback fluid reinjection treatment method of claim 1, wherein: the filtration in the step 3) comprises coarse filtration and fine filtration; the filtration precision of rough filtration is 25-50 μm; the filtering precision of the fine filtration is 1-5 μm.
6. The method for treating the oilfield fracturing flowback fluid by reinjection as claimed in claim 1, wherein the corrosion and scale inhibition bactericide in step 3) is a solution with a mass fraction of 1-10%, and the addition amount is 0.1-1.5L/m3(ii) a The effective components of the corrosion and scale inhibition bactericide consist of a corrosion inhibitor component and a bactericide component.
7. The oilfield frac flowback fluid reinjection treatment method of claim 6, wherein: the effective components of the corrosion and scale inhibition bactericide are prepared from imidazoline quaternary ammonium salt, hydroxy ethylidene diphosphonic acid and dodecyl dimethyl benzyl ammonium bromide according to the mass ratio of 5-15: 1-3: 10-50.
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