CN105441049B - Well fracturing soluble temporarily stifled material, diverting agent, fracturing fluid and preparation method thereof - Google Patents
Well fracturing soluble temporarily stifled material, diverting agent, fracturing fluid and preparation method thereof Download PDFInfo
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- CN105441049B CN105441049B CN201510875578.6A CN201510875578A CN105441049B CN 105441049 B CN105441049 B CN 105441049B CN 201510875578 A CN201510875578 A CN 201510875578A CN 105441049 B CN105441049 B CN 105441049B
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- temporarily stifled
- diverting agent
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- 239000000463 material Substances 0.000 title claims abstract description 40
- 239000012530 fluid Substances 0.000 title claims abstract description 35
- 238000002360 preparation method Methods 0.000 title claims abstract description 9
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 53
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims abstract description 18
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 16
- 239000003999 initiator Substances 0.000 claims abstract description 11
- 239000002994 raw material Substances 0.000 claims abstract description 10
- 150000001991 dicarboxylic acids Chemical class 0.000 claims abstract description 6
- 150000005846 sugar alcohols Polymers 0.000 claims abstract description 6
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims abstract description 5
- 125000001997 phenyl group Chemical group [H]C1=C([H])C([H])=C(*)C([H])=C1[H] 0.000 claims abstract description 5
- 239000000835 fiber Substances 0.000 claims description 20
- 239000002245 particle Substances 0.000 claims description 17
- 238000006243 chemical reaction Methods 0.000 claims description 13
- 238000000034 method Methods 0.000 claims description 13
- 239000000654 additive Substances 0.000 claims description 7
- 230000000996 additive effect Effects 0.000 claims description 7
- VZCYOOQTPOCHFL-OWOJBTEDSA-N Fumaric acid Chemical compound OC(=O)\C=C\C(O)=O VZCYOOQTPOCHFL-OWOJBTEDSA-N 0.000 claims description 6
- -1 alkyl phenol Chemical compound 0.000 claims description 6
- 239000004927 clay Substances 0.000 claims description 6
- 239000003431 cross linking reagent Substances 0.000 claims description 6
- 230000000855 fungicidal effect Effects 0.000 claims description 6
- 239000000417 fungicide Substances 0.000 claims description 6
- 239000003381 stabilizer Substances 0.000 claims description 6
- 238000003756 stirring Methods 0.000 claims description 6
- JAHNSTQSQJOJLO-UHFFFAOYSA-N 2-(3-fluorophenyl)-1h-imidazole Chemical compound FC1=CC=CC(C=2NC=CN=2)=C1 JAHNSTQSQJOJLO-UHFFFAOYSA-N 0.000 claims description 5
- 238000004090 dissolution Methods 0.000 claims description 5
- LVHBHZANLOWSRM-UHFFFAOYSA-N methylenebutanedioic acid Natural products OC(=O)CC(=C)C(O)=O LVHBHZANLOWSRM-UHFFFAOYSA-N 0.000 claims description 5
- QCDWFXQBSFUVSP-UHFFFAOYSA-N 2-phenoxyethanol Chemical compound OCCOC1=CC=CC=C1 QCDWFXQBSFUVSP-UHFFFAOYSA-N 0.000 claims description 4
- ZJCCRDAZUWHFQH-UHFFFAOYSA-N Trimethylolpropane Chemical compound CCC(CO)(CO)CO ZJCCRDAZUWHFQH-UHFFFAOYSA-N 0.000 claims description 4
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 4
- 238000004821 distillation Methods 0.000 claims description 4
- 238000010438 heat treatment Methods 0.000 claims description 4
- 238000002074 melt spinning Methods 0.000 claims description 4
- WXZMFSXDPGVJKK-UHFFFAOYSA-N pentaerythritol Chemical compound OCC(CO)(CO)CO WXZMFSXDPGVJKK-UHFFFAOYSA-N 0.000 claims description 4
- 229960005323 phenoxyethanol Drugs 0.000 claims description 4
- 238000000746 purification Methods 0.000 claims description 4
- 238000010792 warming Methods 0.000 claims description 4
- BTBUEUYNUDRHOZ-UHFFFAOYSA-N Borate Chemical compound [O-]B([O-])[O-] BTBUEUYNUDRHOZ-UHFFFAOYSA-N 0.000 claims description 3
- 239000004971 Cross linker Substances 0.000 claims description 3
- 239000001530 fumaric acid Substances 0.000 claims description 3
- NFHFRUOZVGFOOS-UHFFFAOYSA-N palladium;triphenylphosphane Chemical group [Pd].C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1.C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1.C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1.C1=CC=CC=C1P(C=1C=CC=CC=1)C1=CC=CC=C1 NFHFRUOZVGFOOS-UHFFFAOYSA-N 0.000 claims description 3
- RDBMUARQWLPMNW-UHFFFAOYSA-N phosphanylmethanol Chemical compound OCP RDBMUARQWLPMNW-UHFFFAOYSA-N 0.000 claims description 3
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 3
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 3
- VZCYOOQTPOCHFL-UHFFFAOYSA-N trans-butenedioic acid Natural products OC(=O)C=CC(O)=O VZCYOOQTPOCHFL-UHFFFAOYSA-N 0.000 claims description 3
- DZSVIVLGBJKQAP-UHFFFAOYSA-N 1-(2-methyl-5-propan-2-ylcyclohex-2-en-1-yl)propan-1-one Chemical compound CCC(=O)C1CC(C(C)C)CC=C1C DZSVIVLGBJKQAP-UHFFFAOYSA-N 0.000 claims description 2
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 2
- PZNOBXVHZYGUEX-UHFFFAOYSA-N n-prop-2-enylprop-2-en-1-amine;hydrochloride Chemical compound Cl.C=CCNCC=C PZNOBXVHZYGUEX-UHFFFAOYSA-N 0.000 claims description 2
- 239000012299 nitrogen atmosphere Substances 0.000 claims description 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims 1
- 239000001257 hydrogen Substances 0.000 claims 1
- 229910052739 hydrogen Inorganic materials 0.000 claims 1
- JKQOBWVOAYFWKG-UHFFFAOYSA-N molybdenum trioxide Chemical compound O=[Mo](=O)=O JKQOBWVOAYFWKG-UHFFFAOYSA-N 0.000 claims 1
- KKCBUQHMOMHUOY-UHFFFAOYSA-N sodium oxide Chemical compound [O-2].[Na+].[Na+] KKCBUQHMOMHUOY-UHFFFAOYSA-N 0.000 claims 1
- 229910001948 sodium oxide Inorganic materials 0.000 claims 1
- 239000007787 solid Substances 0.000 abstract description 6
- 239000012153 distilled water Substances 0.000 abstract description 5
- 229920000642 polymer Polymers 0.000 abstract description 5
- QENRKQYUEGJNNZ-UHFFFAOYSA-N 2-methyl-1-(prop-2-enoylamino)propane-1-sulfonic acid Chemical compound CC(C)C(S(O)(=O)=O)NC(=O)C=C QENRKQYUEGJNNZ-UHFFFAOYSA-N 0.000 abstract 1
- 239000003292 glue Substances 0.000 description 19
- 239000000243 solution Substances 0.000 description 19
- 230000035699 permeability Effects 0.000 description 15
- 230000015556 catabolic process Effects 0.000 description 14
- 238000006731 degradation reaction Methods 0.000 description 14
- 238000011084 recovery Methods 0.000 description 9
- 230000015572 biosynthetic process Effects 0.000 description 8
- 238000010276 construction Methods 0.000 description 8
- 238000009987 spinning Methods 0.000 description 8
- 230000006378 damage Effects 0.000 description 6
- 230000000903 blocking effect Effects 0.000 description 5
- 239000000178 monomer Substances 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- IRLPACMLTUPBCL-KQYNXXCUSA-N 5'-adenylyl sulfate Chemical compound C1=NC=2C(N)=NC=NC=2N1[C@@H]1O[C@H](COP(O)(=O)OS(O)(=O)=O)[C@@H](O)[C@H]1O IRLPACMLTUPBCL-KQYNXXCUSA-N 0.000 description 4
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 238000005469 granulation Methods 0.000 description 4
- 230000003179 granulation Effects 0.000 description 4
- 239000007788 liquid Substances 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 150000003839 salts Chemical class 0.000 description 4
- 244000007835 Cyamopsis tetragonoloba Species 0.000 description 3
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 238000004132 cross linking Methods 0.000 description 3
- 238000011056 performance test Methods 0.000 description 3
- 238000003825 pressing Methods 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 229910052708 sodium Inorganic materials 0.000 description 3
- 239000011734 sodium Substances 0.000 description 3
- 238000003786 synthesis reaction Methods 0.000 description 3
- 238000012360 testing method Methods 0.000 description 3
- 230000009466 transformation Effects 0.000 description 3
- XEFAJZOBODPHBG-UHFFFAOYSA-N 1-phenoxyethanol Chemical class CC(O)OC1=CC=CC=C1 XEFAJZOBODPHBG-UHFFFAOYSA-N 0.000 description 2
- ZRALSGWEFCBTJO-UHFFFAOYSA-N Guanidine Chemical compound NC(N)=N ZRALSGWEFCBTJO-UHFFFAOYSA-N 0.000 description 2
- 241000406668 Loxodonta cyclotis Species 0.000 description 2
- 238000005336 cracking Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 239000000155 melt Substances 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 229920002401 polyacrylamide Polymers 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 230000010148 water-pollination Effects 0.000 description 2
- STGNLGBPLOVYMA-MAZDBSFSSA-N (E)-but-2-enedioic acid Chemical compound OC(=O)\C=C\C(O)=O.OC(=O)\C=C\C(O)=O STGNLGBPLOVYMA-MAZDBSFSSA-N 0.000 description 1
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 description 1
- CHJJGSNFBQVOTG-UHFFFAOYSA-N N-methyl-guanidine Natural products CNC(N)=N CHJJGSNFBQVOTG-UHFFFAOYSA-N 0.000 description 1
- GTTSNKDQDACYLV-UHFFFAOYSA-N Trihydroxybutane Chemical compound CCCC(O)(O)O GTTSNKDQDACYLV-UHFFFAOYSA-N 0.000 description 1
- 208000027418 Wounds and injury Diseases 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 235000012216 bentonite Nutrition 0.000 description 1
- 239000002981 blocking agent Substances 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 239000013078 crystal Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000000593 degrading effect Effects 0.000 description 1
- 230000018044 dehydration Effects 0.000 description 1
- 238000006297 dehydration reaction Methods 0.000 description 1
- GQOKIYDTHHZSCJ-UHFFFAOYSA-M dimethyl-bis(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C=CC[N+](C)(C)CC=C GQOKIYDTHHZSCJ-UHFFFAOYSA-M 0.000 description 1
- SWSQBOPZIKWTGO-UHFFFAOYSA-N dimethylaminoamidine Natural products CN(C)C(N)=N SWSQBOPZIKWTGO-UHFFFAOYSA-N 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000011010 flushing procedure Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-M hydroxide Chemical compound [OH-] XLYOFNOQVPJJNP-UHFFFAOYSA-M 0.000 description 1
- 150000004679 hydroxides Chemical class 0.000 description 1
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 208000014674 injury Diseases 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000001151 other effect Effects 0.000 description 1
- 150000004968 peroxymonosulfuric acids Chemical group 0.000 description 1
- 229920000728 polyester Polymers 0.000 description 1
- 239000003755 preservative agent Substances 0.000 description 1
- 230000002335 preservative effect Effects 0.000 description 1
- 230000011218 segmentation Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 230000000638 stimulation Effects 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
-
- 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
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
- C09K8/685—Compositions based on water or polar solvents containing organic compounds containing cross-linking agents
-
- 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
- C09K8/887—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/06—Structured surfactants, i.e. well drilling or treating fluids with a lamellar or spherulitic phase
Abstract
The invention discloses a kind of well fracturing soluble temporarily stifled material, diverting agent, fracturing fluid and preparation method thereof, wherein temporarily stifled material is the polymer prepared by the raw material of following mass percent：The dicarboxylic acids 25 30% of C4 C6；2 acrylamido, 2 methyl propane sulfonic acid 7 10%；The polyalcohol 20 25% of C4 C7；Monohydric alcohol 5 8% with single benzene ring structure；Initiator 0.08 0.15%；Sodium hydroxide 1.5 2%；Distilled water 30%.The temporarily stifled material of the embodiment of the present invention is completely dissolved noresidue solid in different temperatures fracturing fluid environment.
Description
Technical field
The present invention relates to well fracturing field of material technology more particularly to a kind of soluble temporarily stifled materials of well fracturing
Material, diverting agent, fracturing fluid and preparation method thereof.
Background technology
China's low permeability oil field petroleum-in-place enriches, and stock number accounts for about the 30% of national oil total resources,
In proven reserve, the ratio of low-permeability oil deposit accounts for about more than the 2/3 of national reserves, and potentiality to be exploited is huge.Most of hyposmosis
Though reservoir amount of increase in production after fracturing reform is larger, yield is not still high.In recent years, each elephant was adopted in pressing crack construction
With multiple cracking technology in section or crack steering technique, the transformation dynamics to low permeability reservoir is increased, by reservoir maximum production.Turn
To fracturing technique be according to existing for reservoir plane and longitudinal anisotropism and different zones, layer position development degree it is poor
It is different, fracture orientation made to occur to deviate using temporary stifled material, turned to, formed new man-made fracture, open new oil and gas flow channel,
The reservoir that development degree is low or even does not employ is linked up to a greater extent, to achieve the purpose that volume increase.
In order to change the inflow direction of original liquid using the difference of layer intrinsic permeability to achieve the purpose that generate new crack,
Pressing crack construction difficulty can be reduced using diverting agent in the stratum for needing to increase production, reduce the usage quantity of segmentation tool, and carry
The transformation efficiency of high unit well section.Temporarily stifled material is (referred to as temporarily stifled for the solubility that the eastern oil of peace is developed for well fracturing
Agent ADZD).Solubility property test in fracturing fluid is carried out to diverting agent ADZD, and carries out rock core and temporarily blocks up and restore experiment test.
The experimental results showed that diverting agent ADZD is completely dissolved noresidue solid, degradation rate 100% in different temperatures fracturing fluid environment.
In fracturing fluid during diverting agent dosage 1%, rock core temporarily blocks up rate and can reach 96.9%, and recovery of core permeability can after diverting agent degradation
Reach 97.7%.Illustrate that the diverting agent developed not only has good temporarily stifled turning efficiency, but also to formation damage after degradation
Very little.
Temporary plugging technique has applied to all kinds of construction operations of Oil Field at present, including drilling well, well cementation, well workover, well-flushing with
And well stimulation etc., each elephant start in pressing crack construction using multiple cracking technology in section or the increasing pair of crack steering technique
The transformation dynamics of low permeability reservoir, thus by reservoir maximum production.For the temporary stifled material of well fracturing mainly have at present by
The diverting agent and the diverting agent of cross-linked, water-soluble Macroscopic single crystal that inorganic salts and water-soluble component are mixed to prepare.By inorganic salts and
Diverting agent made from water-soluble component not only possesses excellent water solubility, plugging strength is higher and solution rate faster, both may be used
It constructs again available for the fracture acidizing of well for oil well.Crosslinking polymer diverting agent is divided into granular pattern and rubber plug type, passes through
Crosslinked method obtains being dried after full-bodied fluid, shears, is granulated the particle for being formed and can be used for temporarily blocking up, and can also pass through friendship
The method of connection forms temporarily stifled rubber plug after forming high viscosity fluid injection stratum.But the either diverting agent system of solid or liquid,
It is dissolved in the water since its own cannot degrade, addition gel breaker is required for make its broken glue and then system is made smoothly to return discharge ground
Layer.In addition also there is certain application as diverting agent by the polymer based on polyacrylamide, and its plugging strength and temporarily
Stifled rate can also meet the requirement of site operation, but have higher viscosity after its degradation, make fracturing fluid viscosity rise without
Conducive to the row of returning after construction, larger injury can be caused to stratum.
The defects of existing all kinds of diverting agents have certain temporarily stifled performance but also have its own, the body being made of inorganic salts
Permanent blockage can be caused to stratum by tying up to inorganic salts release in course of dissolution, be unfavorable for later stage oil-gas mining；Cross-linking type polymerize
Object, which needs to add in gel breaker after construction, could break glue, can increase construction week in temporary stifled time longer construction operation is needed
Phase causes cost increase, while crosslinking polymer solubility property is poor, and partly cannot break glue completely in fracturing fluid equally can
Stratum is trapped in, is influencing later stage recovery process；Fracturing fluid viscosity can be made to increase after the dissolving of PAM classes diverting agent, be unfavorable for pressure break
The row of returning of liquid.
Invention content
In view of this, the embodiment of the present invention provides a kind of well fracturing soluble temporarily stifled material, and main purpose is to carry
For the good temporarily stifled material of dissolubility.
In order to achieve the above objectives, present invention generally provides following technical solutions：
On the one hand, it is by following matter an embodiment of the present invention provides a kind of soluble temporarily stifled material of well fracturing
Measure polymer prepared by the raw material of percentage：
Preferably, the dicarboxylic acids of the C4-C6 selects itaconic acid or fumaric acid.
Preferably, the polyalcohol of the C4-C7 selects trimethylolpropane or pentaerythrite.
Preferably, the monohydric alcohol with single benzene ring structure selects Phenoxyethanol.
Preferably, the molecular weight of the polyester is 15000-18500.
On the other hand, an embodiment of the present invention provides a kind of diverting agents, and the raw material of the diverting agent is above-described embodiment
Temporarily stifled material.
Preferably, the diverting agent is temporarily stifled particle, the grain size of the temporarily stifled particle is 5-8mm.
Preferably, the diverting agent is temporarily stifled fiber, the length of the temporarily stifled fiber is 5-10mm.
Preferably, the temporarily stifled fiber is molded by melt spinning process.
On the other hand, an embodiment of the present invention provides a kind of fracturing fluid, the fracturing fluid includes diverting agent, described temporarily stifled
Agent is the diverting agent described in above-described embodiment, and the mass percent that the diverting agent accounts for fracturing fluid is 1-4%.
Preferably, the fracturing fluid is made of the component of following mass percent：
Surplus is water.
Preferably, the fungicide is tetrakis hydroxymetyl phosphonium sulfuric；The cleanup additive is alkyl phenol polyoxyethylene ether；It is described
Clay stabilizer is polydimethyl diallyl ammonium chloride；The temperature stability agent is sodium hydroxide；The crosslinking agent is organic
Borate crosslinker；It is described to have gel breaker for ammonium persulfate.
Another method, the embodiment of the present invention provides the preparation method that a kind of above-described embodiment temporarily blocks up material, including walking as follows
Suddenly：
In a nitrogen atmosphere, the polyalcohol of the dicarboxylic acids of C4-C6 (with distillation water dissolution) and C4-C7 is added in reaction to hold
In device and stir；Then it adds in part initiator and is gradually heating to 100-110 DEG C, keep the temperature addition hydroxide after 25-30min
The 2- acrylamide-2-methylpro panesulfonic acid solution that sodium neutralizes；Then 140-160 DEG C will be risen to and keep the temperature 0.5h；Then by band
It is reacted in the monohydric alcohol addition system for having single benzene ring structure, and adds in remaining initiator and be warming up to 160-180 DEG C, reaction 2h
After cool down；Obtained product is subjected to purification after the completion of reaction and is dried to obtain soluble temporarily stifled material；What is wherein added in is remaining
The mass percent that initiator accounts for total raw material is 0.02-0.03%.
Compared with prior art, the beneficial effects of the present invention are：
The temporarily stifled material of the embodiment of the present invention is completely dissolved noresidue solid, degradation rate in different temperatures fracturing fluid environment
100%.When diverting agent made of the temporarily stifled material for the embodiment of the present invention that mass percent is 1% is added in fracturing fluid, rock core
Temporarily stifled rate can reach 96.9%, and recovery of core permeability can reach 97.7% after diverting agent degradation.Illustrate the embodiment of the present invention
Temporarily stifled material not only there is good temporarily stifled turning efficiency, but also to formation damage very little after degrading.It can be in Low Permeability Oil/gas
It is promoted the use of in well and old well volume increase recovery process, can effectively improve yield, and formation damage is minimized.
Specific embodiment
The present invention is described in further detail, but not as a limitation of the invention with reference to specific embodiment.
In the description below, what different " embodiment " or " embodiment " referred to is not necessarily the same embodiment.In addition, one or more are implemented
Special characteristic, structure or feature in example can be combined by any suitable form.
Embodiment one：
Reaction system is led into nitrogen displaced air, then according to mass ratio by fumaric acid (fumaric acid) and pentaerythrite
Monomer adds in four round flask and starts stirring, and wherein fumaric acid 98.5g, which is added in 100g distilled water, fully to be dissolved, and is added in
Pentaerythrite 110g；Then 0.32g initiators are added in and system is gradually heating to 100 DEG C, are added after keeping the temperature 25min into system
Enter the AMPS solution neutralized with sodium hydroxide and (use distillation water dissolution, AMPS25g is added in 25g distilled water, then adds in 4g hydrogen-oxygens
Change sodium).Then system temperature is risen to 140 DEG C and keeps the temperature 0.5h.Then the reaction of 15g Phenoxyethanols is added in into reaction system,
And add 0.08g initiators and be warming up to 165 DEG C, cool down after reacting 2h.Obtained product is carried out purification after the completion of reaction to do
It is dry to obtain product.Raw material is ground into using high speed disintegrator powdered spare.The product molecule structural formula finally synthesized is as follows：
Molecular weight of product is 15000-16500.
Embodiment two：
Reaction system is led into nitrogen displaced air, then adds in itaconic acid and trimethylolpropane monomer according to mass ratio
In four round flask and stirring is started, wherein itaconic acid 105g, which is added in 100g distilled water, fully to be dissolved, and adds in trihydroxy methyl
Propane 97g；Then 0.30g initiators are added in and system is gradually heating to 105 DEG C, use is added in into system after keeping the temperature 30min
(with distillation water dissolution, AMPS21g is added in 30g distilled water the AMPS solution that sodium hydroxide neutralizes, and then adds in 4g hydroxides
Sodium).Then system temperature is risen to 150 DEG C and keeps the temperature 0.5h.Then the reaction of 14.5g Phenoxyethanols is added in into reaction system,
And add 0.12g initiators and be warming up to 180 DEG C, cool down after reacting 2h.Obtained product is carried out purification after the completion of reaction to do
It is dry to obtain product.Raw material is ground into using high speed disintegrator powdered spare.The product molecule structural formula finally synthesized is as follows：
Molecular weight is 16500-18500.
Temporarily stifled material to ensure to obtain has preferable hydrophily, and the embodiment of the present invention uses synthesis main chain as linear junction
Structure, and using itaconic acid and containing there are three main body of the trimethylolpropane of hydroxyl as soluble temporarily stifled materials synthesis monomer
Raw material, while in order to improve the heat resistance of material and intensity, introducing Phenoxyethanol and utilize it as segment closed-end structure,
Its rigid chain maintains the solid structure and heat resistance of material, while hydrophilic monomer AMPS is introduced on main chain, keeps its excellent
Good water solubility.
Embodiment three：
It is molded using melt spinning process.Temporarily stifled material slice adds the solubility that embodiment one is obtained in screw extruder
Heat fusing enters spinning-drawing machine into melt after preparatory process before spinning, spinning melt is quantified with spinning pump (metering pump), continuously,
It equably extrudes from the pore of spinning head, then cools and solidifies in air, generate as-spun fibre, be then cut into as length 5-
The fiber of 10mm obtains temporarily blocking up fiber.
The soluble temporarily stifled material that embodiment one obtains by screw extruder is heated and melts and squeezes out, with granulation machine-cut
Granulation is cut, is shaped to particle of the grain size in 5-8mm, obtains temporarily blocking up particle.
Example IV：
It is molded using melt spinning process.Temporarily stifled material slice adds the solubility that embodiment two is obtained in screw extruder
Heat fusing enters spinning-drawing machine into melt after preparatory process before spinning, spinning melt is quantified with spinning pump (metering pump), continuously,
It equably extrudes from the pore of spinning head, then cools and solidifies in air, generate as-spun fibre, be then cut into as length 5-
The fiber of 10mm obtains temporarily blocking up fiber.
The soluble temporarily stifled material that embodiment two obtains by screw extruder is heated and melts and squeezes out, with granulation machine-cut
Granulation is cut, is shaped to particle of the grain size in 5-8mm, obtains temporarily blocking up particle.
Embodiment five：
The component and mass percent of fracturing fluid are as follows：0.4% hydroxypropyl guar, 0.1% fungicide, 0.5% cleanup additive,
0.5% clay stabilizer, 0.1% temperature stability agent, 0.4% crosslinking agent, 300ppm gel breakers, 1%, which temporarily blocks up fiber and 1%, temporarily blocks up
Particle.Fungicide is tetrakis hydroxymetyl phosphonium sulfuric in the present embodiment, and cleanup additive is alkyl phenol polyoxyethylene ether, and clay stabilizer is poly-
Dimethyl diallyl ammonium chloride, temperature stability agent are sodium hydroxide, and crosslinking agent is organic borate cross-linker, and gel breaker is persulfuric acid
Ammonium.
Pressure break liquid making method：500ml water is measured in beaker, is subsequently placed under blender and is slowly added to 2g guanidine glue, open
Opening blender stir about 10min makes it fully be swollen, and then sequentially adds the additive in formula according to mass ratio and stirs equal
It is even to obtain fracturing fluid.
Temporarily stifled fiber and particle use three resulting product of embodiment.
It is tested at 90 DEG C, diverting agent the performance test results see the table below 1：
100ml fracturing fluids is taken to be placed in beaker and be then respectively adding 1g temporarily to block up fiber and particle and sealed with preservative film, will be burnt
Cup is placed in 90 DEG C of thermostat water baths and observes whether fiber is completely dissolved with particle and records its degradable time；It will be artificial
Core permeability K1 is surveyed after core (known permeability is K0) first positive logical plus diverting agent fracturing fluid, is then surveyed after logical brine
Obtain permeability K2.Temporarily stifled rate is calculated by formula (K0-K1)/K0, recovery of core permeability is calculated by formula K2/K0；It is broken
Glue (is cooled to room temperature) viscosity and is tested with six fast rotational viscometers；Cases of dehydration is observed after breaking glue solution is mixed with oil sample and is remembered
Record；Surface tension is tested with surface tension instrument；Anti-dilative is tested with centrifugal process, is weighed 0.5g bentonites and is added in centrifuge tube, so
10ml breaking glue solutions are added in afterwards to shake up, and are placed 2h and are placed on separation in centrifuge (1500r, 15min) and then measure.
Table 1
| Project | Index |
| Degradation time, h | 14 |
| Degradation rate, % | 100 |
| Temporarily stifled rate, % | 96.6 |
| Recovery of core permeability, % | 97.3 |
| Breaking glue solution viscosity after dissolving, mPas | 3 |
| Breaking glue solution demulsification efficiency after dissolving, % | 100 |
| Breaking glue solution surface tension after dissolving, mN/m | 26.4 |
| Breaking glue solution anti-dilative after dissolving, % | 87.5 |
Embodiment six：
Fracturing fluid is prepared with test according to method and step in embodiment five.It is component and quality hundred with five difference of embodiment
Divide than (wherein temporarily stifled fiber and particle use resulting product in example IV)：+ 0.1% fungicide of 0.45% hydroxypropyl guar+
+ 0.5% crosslinking agent+400ppm gel breakers+1.5% of+0.2% temperature stability agent of+0.5% clay stabilizer of 0.5% cleanup additive are temporarily
Stifled fiber+1.5% temporarily blocks up particle, obtains fracturing fluid.
It is tested at 120 DEG C, diverting agent the performance test results see the table below 2：
Table 2
| Project | Index |
| Degradation time, h | 10 |
| Degradation rate, % | 100 |
| Temporarily stifled rate, % | 96.9 |
| Recovery of core permeability, % | 97.7 |
| Breaking glue solution viscosity after dissolving, mPas | 1.5 |
| Breaking glue solution demulsification efficiency after dissolving, % | 100 |
| Breaking glue solution surface tension after dissolving, mN/m | 25.9 |
| Breaking glue solution anti-dilative after dissolving, % | 89.0 |
Embodiment seven：
It is that the component of fracturing fluid and mass percent (wherein temporarily block up fiber and particle using implementation with five difference of embodiment
Resulting product in example four)：+ 0.5% clay stabilizer+0.3% of+0.5% cleanup additive of+0.1% fungicide of 0.5% hydroxypropyl guar
Temporarily stifled fiber+2% temporarily blocks up particle to+0.6% crosslinking agent+500ppm gel breakers+2% of temperature stability agent, obtains fracturing fluid.
It is tested at 150 DEG C, diverting agent the performance test results see the table below 3：
Table 3
| Project | Index |
| Degradation time, h | 8.5 |
| Degradation rate, % | 100 |
| Temporarily stifled rate, % | 95.8 |
| Recovery of core permeability, % | 97.2 |
| Breaking glue solution viscosity after dissolving, mPas | 1.5 |
| Breaking glue solution demulsification efficiency after dissolving, % | 100 |
| Breaking glue solution surface tension after dissolving, mN/m | 25.6 |
| Breaking glue solution anti-dilative after dissolving, % | 91.1 |
Temporarily stifled material to ensure to obtain has preferable hydrophily, and the embodiment of the present invention uses synthesis main chain as linear junction
Structure, and using the synthon of the dicarboxylic acids of C4-C6 and the polyalcohol of C4-C7 as soluble temporarily stifled material, be simultaneously
The heat resistance and intensity of material are improved, Phenoxyethanol is introduced and utilizes it as segment closed-end structure, rigid chain is protected
The solid structure and heat resistance of material have been held, while hydrophilic monomer AMPS is introduced on main chain, has kept its excellent water solubility.
Each component and proportioning in the fracturing fluid of the embodiment of the present invention can be selected arbitrarily in the prior art, as long as wherein
Diverting agent can reach rock core using diverting agent provided by the invention and temporarily block up rate and can reach 96.9%, rock core after diverting agent degradation
Resume permeability rate can reach 97.7% and other effects.The fracturing fluid of the embodiment of the present invention employs provided in an embodiment of the present invention temporary
Blocking agent has good temporarily stifled turning efficiency, and to formation damage very little after degradation.Diverting agent containing the embodiment of the present invention
Fracturing fluid can low-permeability oil gas well and old well volume increase recovery process in promote the use of, can effectively improve yield,
And formation damage is minimized.
The above description is merely a specific embodiment, but protection scope of the present invention is not limited thereto, any
Those familiar with the art in the technical scope disclosed by the present invention, can readily occur in change or replacement, should all contain
Lid is within protection scope of the present invention.Therefore, protection scope of the present invention should be based on the protection scope of the described claims.
Claims (12)
1. the well fracturing preparation method of soluble temporarily stifled material, includes the following steps：
In a nitrogen atmosphere, it by the distillation water dissolution of the dicarboxylic acids of C4-C6, is added in reaction vessel with the polyalcohol of C4-C7
And it stirs；Then 0.06-0.12% initiators are added in and are gradually heating to 100-105 DEG C, keep the temperature addition hydrogen after 25-30min
The 2- acrylamide-2-methylpro panesulfonic acid solution that sodium oxide molybdena neutralizes；Then system temperature is risen to 140-160 DEG C and kept the temperature
0.5h；Then it will be reacted, and add in remaining initiator and be warming up in the monohydric alcohol addition system with single benzene ring structure
160-180 DEG C, cool down after reacting 2h；Obtained product is subjected to purification after the completion of reaction and is dried to obtain well fracturing with solvable
Property temporarily block up material；The mass percent that the remaining initiator wherein added in accounts for total raw material is 0.02-0.03%；
Wherein, raw material by percentage to the quality, including：
2. the well fracturing according to claim 1 preparation method of soluble temporarily stifled material, which is characterized in that described
The dicarboxylic acids of C4-C6 selects itaconic acid or fumaric acid.
3. the well fracturing according to claim 1 preparation method of soluble temporarily stifled material, which is characterized in that described
The polyalcohol of C4-C7 selects trimethylolpropane or pentaerythrite.
4. the well fracturing according to claim 1 preparation method of soluble temporarily stifled material, which is characterized in that described
Monohydric alcohol with single benzene ring structure selects Phenoxyethanol.
5. the soluble temporarily stifled material of well fracturing, which is characterized in that prepared by claim 1-4 any one of them method
And it obtains；The well fracturing is 15000-18500 with the molecular weight of soluble temporarily stifled material.
6. diverting agent, which is characterized in that the raw material of the diverting agent is the temporarily stifled material described in claim 5.
7. diverting agent according to claim 6, which is characterized in that the diverting agent is temporarily stifled particle, the temporarily stifled particle
Grain size be 5-8mm.
8. diverting agent according to claim 6, which is characterized in that the diverting agent is temporarily stifled fiber, the temporarily stifled fiber
Length be 5-10mm.
9. diverting agent according to claim 8, which is characterized in that the temporarily stifled fiber is molded by melt spinning process.
10. fracturing fluid, including diverting agent, the diverting agent is the diverting agent described in claim 6, and the diverting agent accounts for fracturing fluid
Mass percent be 1-4%.
11. fracturing fluid according to claim 10, which is characterized in that the fracturing fluid by following mass percent component
Composition：
12. fracturing fluid according to claim 11, which is characterized in that the fungicide is tetrakis hydroxymetyl phosphonium sulfuric；It is described
Cleanup additive is alkyl phenol polyoxyethylene ether；The clay stabilizer is polydimethyl diallyl ammonium chloride；The temperature is stablized
Agent is sodium hydroxide；The crosslinking agent is organic borate cross-linker；It is described to have gel breaker for ammonium persulfate.
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| CN107828010B (en) * | 2017-11-03 | 2021-01-15 | 四川晨瑞石油化工有限责任公司 | Polymer, temporary plugging agent and preparation method thereof |
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|---|---|---|---|---|
| US4689266A (en) * | 1986-07-16 | 1987-08-25 | International Minerals & Chemical Corp. | Air drying protective coatings |
| WO2003022902A1 (en) * | 2001-09-06 | 2003-03-20 | Bayer Materialscience Ag | Radiation-curable urethane acrylates, based on a blend of various oxyalkylated polyols |
| CN1751075A (en) * | 2003-03-14 | 2006-03-22 | 巴斯夫公司 | Graft polymers and use thereof in cosmetic formulations |
| CN1930254B (en) * | 2004-03-15 | 2011-07-20 | 文都书写颜料有限责任两合公司 | Non-aqueous polar ink composition |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4689266A (en) * | 1986-07-16 | 1987-08-25 | International Minerals & Chemical Corp. | Air drying protective coatings |
| WO2003022902A1 (en) * | 2001-09-06 | 2003-03-20 | Bayer Materialscience Ag | Radiation-curable urethane acrylates, based on a blend of various oxyalkylated polyols |
| CN1751075A (en) * | 2003-03-14 | 2006-03-22 | 巴斯夫公司 | Graft polymers and use thereof in cosmetic formulations |
| CN1930254B (en) * | 2004-03-15 | 2011-07-20 | 文都书写颜料有限责任两合公司 | Non-aqueous polar ink composition |
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