CN115960306B - Raw material composition, filtrate reducer for drilling fluid, and preparation method and application thereof - Google Patents
Raw material composition, filtrate reducer for drilling fluid, and preparation method and application thereof Download PDFInfo
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- CN115960306B CN115960306B CN202111179435.3A CN202111179435A CN115960306B CN 115960306 B CN115960306 B CN 115960306B CN 202111179435 A CN202111179435 A CN 202111179435A CN 115960306 B CN115960306 B CN 115960306B
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- 239000012530 fluid Substances 0.000 title claims abstract description 75
- 238000005553 drilling Methods 0.000 title claims abstract description 74
- 239000000706 filtrate Substances 0.000 title claims abstract description 56
- 239000003638 chemical reducing agent Substances 0.000 title claims abstract description 50
- 239000000203 mixture Substances 0.000 title claims abstract description 31
- 238000002360 preparation method Methods 0.000 title claims abstract description 7
- 239000002994 raw material Substances 0.000 title claims description 31
- 239000000178 monomer Substances 0.000 claims abstract description 112
- 239000000654 additive Substances 0.000 claims abstract description 52
- 230000000996 additive effect Effects 0.000 claims abstract description 50
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 22
- 239000002904 solvent Substances 0.000 claims abstract description 9
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 54
- 238000006116 polymerization reaction Methods 0.000 claims description 35
- 125000000217 alkyl group Chemical group 0.000 claims description 28
- 239000001257 hydrogen Substances 0.000 claims description 27
- 229910052739 hydrogen Inorganic materials 0.000 claims description 27
- 238000000034 method Methods 0.000 claims description 22
- 239000004280 Sodium formate Substances 0.000 claims description 21
- HLBBKKJFGFRGMU-UHFFFAOYSA-M sodium formate Chemical compound [Na+].[O-]C=O HLBBKKJFGFRGMU-UHFFFAOYSA-M 0.000 claims description 21
- 235000019254 sodium formate Nutrition 0.000 claims description 21
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 19
- 239000003999 initiator Substances 0.000 claims description 18
- 229920000642 polymer Polymers 0.000 claims description 18
- 150000002431 hydrogen Chemical class 0.000 claims description 16
- 230000000379 polymerizing effect Effects 0.000 claims description 15
- 239000012986 chain transfer agent Substances 0.000 claims description 12
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 11
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 10
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 claims description 10
- 125000000753 cycloalkyl group Chemical group 0.000 claims description 8
- 125000001495 ethyl group Chemical group [H]C([H])([H])C([H])([H])* 0.000 claims description 8
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 6
- 239000000126 substance Substances 0.000 claims description 6
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 5
- CWERGRDVMFNCDR-UHFFFAOYSA-N thioglycolic acid Chemical compound OC(=O)CS CWERGRDVMFNCDR-UHFFFAOYSA-N 0.000 claims description 4
- OZAIFHULBGXAKX-UHFFFAOYSA-N 2-(2-cyanopropan-2-yldiazenyl)-2-methylpropanenitrile Chemical compound N#CC(C)(C)N=NC(C)(C)C#N OZAIFHULBGXAKX-UHFFFAOYSA-N 0.000 claims description 3
- KGMXPXPXPAAUMD-UHFFFAOYSA-N propane;dihydrochloride Chemical compound Cl.Cl.CCC KGMXPXPXPAAUMD-UHFFFAOYSA-N 0.000 claims description 3
- AEUVIXACNOXTBX-UHFFFAOYSA-N 1-sulfanylpropan-1-ol Chemical compound CCC(O)S AEUVIXACNOXTBX-UHFFFAOYSA-N 0.000 claims description 2
- DKIDEFUBRARXTE-UHFFFAOYSA-N 3-mercaptopropanoic acid Chemical compound OC(=O)CCS DKIDEFUBRARXTE-UHFFFAOYSA-N 0.000 claims description 2
- KWSLGOVYXMQPPX-UHFFFAOYSA-N 5-[3-(trifluoromethyl)phenyl]-2h-tetrazole Chemical compound FC(F)(F)C1=CC=CC(C2=NNN=N2)=C1 KWSLGOVYXMQPPX-UHFFFAOYSA-N 0.000 claims description 2
- 125000002947 alkylene group Chemical group 0.000 claims description 2
- DNJIEGIFACGWOD-UHFFFAOYSA-N ethyl mercaptane Natural products CCS DNJIEGIFACGWOD-UHFFFAOYSA-N 0.000 claims description 2
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 2
- 229910001379 sodium hypophosphite Inorganic materials 0.000 claims description 2
- DGVVWUTYPXICAM-UHFFFAOYSA-N β‐Mercaptoethanol Chemical compound OCCS DGVVWUTYPXICAM-UHFFFAOYSA-N 0.000 claims description 2
- 238000004519 manufacturing process Methods 0.000 claims 12
- 239000012966 redox initiator Substances 0.000 claims 1
- 229920001577 copolymer Polymers 0.000 abstract description 35
- 239000011575 calcium Substances 0.000 abstract description 21
- 229910052791 calcium Inorganic materials 0.000 abstract description 21
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 abstract description 18
- -1 salt ions Chemical class 0.000 abstract description 7
- BDAGIHXWWSANSR-UHFFFAOYSA-M Formate Chemical compound [O-]C=O BDAGIHXWWSANSR-UHFFFAOYSA-M 0.000 abstract description 6
- 125000000524 functional group Chemical group 0.000 abstract description 3
- 230000002441 reversible effect Effects 0.000 abstract description 2
- 230000009881 electrostatic interaction Effects 0.000 abstract 1
- 239000000243 solution Substances 0.000 description 55
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 32
- 238000001035 drying Methods 0.000 description 21
- 238000003756 stirring Methods 0.000 description 21
- XHZPRMZZQOIPDS-UHFFFAOYSA-N 2-Methyl-2-[(1-oxo-2-propenyl)amino]-1-propanesulfonic acid Chemical compound OS(=O)(=O)CC(C)(C)NC(=O)C=C XHZPRMZZQOIPDS-UHFFFAOYSA-N 0.000 description 18
- 239000002245 particle Substances 0.000 description 18
- 229920000536 2-Acrylamido-2-methylpropane sulfonic acid Polymers 0.000 description 17
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 17
- 150000003839 salts Chemical class 0.000 description 17
- 238000012216 screening Methods 0.000 description 17
- 239000008367 deionised water Substances 0.000 description 16
- 229910021641 deionized water Inorganic materials 0.000 description 16
- 238000010438 heat treatment Methods 0.000 description 16
- 229910052757 nitrogen Inorganic materials 0.000 description 16
- 238000006243 chemical reaction Methods 0.000 description 15
- 230000000052 comparative effect Effects 0.000 description 15
- 238000005086 pumping Methods 0.000 description 15
- 229940088644 n,n-dimethylacrylamide Drugs 0.000 description 14
- YLGYACDQVQQZSW-UHFFFAOYSA-N n,n-dimethylprop-2-enamide Chemical compound CN(C)C(=O)C=C YLGYACDQVQQZSW-UHFFFAOYSA-N 0.000 description 14
- JMAVMPUTSJKGIJ-UHFFFAOYSA-N 2-prop-2-enoyloxypropane-1,2,3-tricarboxylic acid Chemical compound OC(=O)CC(CC(O)=O)(C(O)=O)OC(=O)C=C JMAVMPUTSJKGIJ-UHFFFAOYSA-N 0.000 description 13
- NJSSICCENMLTKO-HRCBOCMUSA-N [(1r,2s,4r,5r)-3-hydroxy-4-(4-methylphenyl)sulfonyloxy-6,8-dioxabicyclo[3.2.1]octan-2-yl] 4-methylbenzenesulfonate Chemical compound C1=CC(C)=CC=C1S(=O)(=O)O[C@H]1C(O)[C@@H](OS(=O)(=O)C=2C=CC(C)=CC=2)[C@@H]2OC[C@H]1O2 NJSSICCENMLTKO-HRCBOCMUSA-N 0.000 description 13
- 238000001914 filtration Methods 0.000 description 7
- 230000000694 effects Effects 0.000 description 6
- 239000012065 filter cake Substances 0.000 description 6
- 239000000047 product Substances 0.000 description 6
- 239000008186 active pharmaceutical agent Substances 0.000 description 5
- 239000003795 chemical substances by application Substances 0.000 description 5
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 4
- 230000032683 aging Effects 0.000 description 4
- 229910001424 calcium ion Inorganic materials 0.000 description 4
- 239000001913 cellulose Substances 0.000 description 4
- 229920002678 cellulose Polymers 0.000 description 4
- 230000001276 controlling effect Effects 0.000 description 4
- 238000011282 treatment Methods 0.000 description 4
- SYPKYPCQNDILJH-UHFFFAOYSA-N 2-methyl-2-(prop-2-enoylamino)butane-1-sulfonic acid Chemical compound OS(=O)(=O)CC(C)(CC)NC(=O)C=C SYPKYPCQNDILJH-UHFFFAOYSA-N 0.000 description 3
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 3
- 230000002209 hydrophobic effect Effects 0.000 description 3
- 230000006698 induction Effects 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 239000001301 oxygen Substances 0.000 description 3
- 229910052760 oxygen Inorganic materials 0.000 description 3
- WFIZEGIEIOHZCP-UHFFFAOYSA-M potassium formate Chemical compound [K+].[O-]C=O WFIZEGIEIOHZCP-UHFFFAOYSA-M 0.000 description 3
- 230000001603 reducing effect Effects 0.000 description 3
- 239000002002 slurry Substances 0.000 description 3
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 150000001409 amidines Chemical class 0.000 description 2
- 239000007864 aqueous solution Substances 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 238000005469 granulation Methods 0.000 description 2
- 230000003179 granulation Effects 0.000 description 2
- 230000036571 hydration Effects 0.000 description 2
- 238000006703 hydration reaction Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000010298 pulverizing process Methods 0.000 description 2
- 230000001105 regulatory effect Effects 0.000 description 2
- JHJLBTNAGRQEKS-UHFFFAOYSA-M sodium bromide Chemical compound [Na+].[Br-] JHJLBTNAGRQEKS-UHFFFAOYSA-M 0.000 description 2
- 239000007790 solid phase Substances 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- RRHXZLALVWBDKH-UHFFFAOYSA-M trimethyl-[2-(2-methylprop-2-enoyloxy)ethyl]azanium;chloride Chemical compound [Cl-].CC(=C)C(=O)OCC[N+](C)(C)C RRHXZLALVWBDKH-UHFFFAOYSA-M 0.000 description 2
- 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 description 1
- BFABTDLHJZNAAX-UHFFFAOYSA-N 2-(2-methylprop-2-enoyloxy)propane-1,2,3-tricarboxylic acid Chemical group CC(=C)C(=O)OC(CC(O)=O)(CC(O)=O)C(O)=O BFABTDLHJZNAAX-UHFFFAOYSA-N 0.000 description 1
- 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 1
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 229920000881 Modified starch Polymers 0.000 description 1
- 239000004368 Modified starch Substances 0.000 description 1
- 229910019142 PO4 Inorganic materials 0.000 description 1
- 238000004220 aggregation Methods 0.000 description 1
- 230000002776 aggregation Effects 0.000 description 1
- NKQIMNKPSDEDMO-UHFFFAOYSA-L barium bromide Chemical compound [Br-].[Br-].[Ba+2] NKQIMNKPSDEDMO-UHFFFAOYSA-L 0.000 description 1
- 229910001620 barium bromide Inorganic materials 0.000 description 1
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 1
- 239000010428 baryte Substances 0.000 description 1
- 229910052601 baryte Inorganic materials 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000000440 bentonite Substances 0.000 description 1
- 229910000278 bentonite Inorganic materials 0.000 description 1
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 239000000872 buffer Substances 0.000 description 1
- 230000009920 chelation Effects 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- IOMDIVZAGXCCAC-UHFFFAOYSA-M diethyl-bis(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C=CC[N+](CC)(CC)CC=C IOMDIVZAGXCCAC-UHFFFAOYSA-M 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
- 238000005516 engineering process Methods 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 125000000623 heterocyclic group Chemical group 0.000 description 1
- 238000009775 high-speed stirring Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 230000000977 initiatory effect Effects 0.000 description 1
- 150000007529 inorganic bases Chemical class 0.000 description 1
- 229910017053 inorganic salt Inorganic materials 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 239000003077 lignite Substances 0.000 description 1
- 239000000314 lubricant Substances 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 239000011259 mixed solution Substances 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 235000019426 modified starch Nutrition 0.000 description 1
- OVHHHVAVHBHXAK-UHFFFAOYSA-N n,n-diethylprop-2-enamide Chemical compound CCN(CC)C(=O)C=C OVHHHVAVHBHXAK-UHFFFAOYSA-N 0.000 description 1
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 description 1
- 239000010452 phosphate Substances 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000010526 radical polymerization reaction Methods 0.000 description 1
- 238000012827 research and development Methods 0.000 description 1
- 238000005096 rolling process Methods 0.000 description 1
- 238000005185 salting out Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 238000007873 sieving Methods 0.000 description 1
- 229910000030 sodium bicarbonate Inorganic materials 0.000 description 1
- 235000017557 sodium bicarbonate Nutrition 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 125000000542 sulfonic acid group Chemical group 0.000 description 1
- 239000000230 xanthan gum Substances 0.000 description 1
- 229920001285 xanthan gum Polymers 0.000 description 1
- 235000010493 xanthan gum Nutrition 0.000 description 1
- 229940082509 xanthan gum Drugs 0.000 description 1
Classifications
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/141—Feedstock
Landscapes
- Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
Abstract
The invention relates to a filtrate reducer for drilling fluid, and a preparation method and application thereof. The fluid loss additive comprises a five-membered co-polymer comprising structural units derived from monomer a, monomer B, monomer C, monomer D, and monomer E. The preparation method of the filtrate reducer for the drilling fluid comprises the following steps: the feed system comprising the feed composition and the solvent is polymerized to produce the fluid loss additive. The invention also comprises the application of the fluid loss additive for drilling fluid in the drilling fluid, in particular to the application of the fluid loss additive. The filtrate reducer of the invention introduces a supermolecular chemistry theory, and utilizes the electrostatic interaction between salt ions in formate water and functional groups on a molecular chain of the filtrate reducer to form a reversible and stable three-dimensional space network structure, thereby remarkably improving the temperature resistance and the calcium resistance of the filtrate reducer.
Description
Technical Field
The invention relates to the technical field of oilfield drilling fluid, in particular to a raw material composition for preparing a fluid loss additive for drilling fluid, a polymer prepared according to the raw material composition, the fluid loss additive for drilling fluid, a preparation method and application thereof.
Background
The solid phase of clay, barite and the like in the drilling fluid is one of important factors causing damage to hydrocarbon reservoirs and reducing productivity, and the solid-free drilling fluid system can be used as an effective means for effectively solving the damage of the solid phase in the drilling fluid to the reservoir. Solid-free drilling fluid systems generally refer to drilling fluid systems that do not contain clay and insoluble solid weighting materials, the density of which is adjusted by soluble salts, and other properties of the system are achieved by the addition of a co-processing agent. The solid-free system can be divided into inorganic salt solid-free drilling fluid and organic salt solid-free drilling fluid according to the different soluble salts. Inorganic salts mainly include NaCl, caCl 2、KCl、NaBr、BaBr2, phosphate and the like, and organic salts mainly include formate, such as: naCOOH, KCOOH, csCOOH, etc. Other compatible treatments are mainly tackifier, cutting agent, filtrate reducer, lubricant, corrosion inhibitor, buffer agent, etc.
The filtrate reducer is one of the key treatment agents in the solid-free drilling fluid and is the key for maintaining the filtrate loss wall-building performance of the whole system. The solid-free drilling fluid system does not contain bentonite, so that a filter cake is completely formed by natural high polymers or polymers in the system. The network structure formed by interweaving polymer tackifier molecules with larger molecular weight becomes the main body of the filter cake, and the filter loss agent molecules with relatively lower molecular weight curl into spheres to block the micropores of the filter cake, so that the filter cake is thin and fine.
In the prior art, the filtrate reducer applied to the solid-free drilling fluid system comprises a natural modified polymer represented by modified starch and modified cellulose. For example, the literature "development of novel high temperature resistant solid-free completion fluid" in 2011, 3, discloses a high temperature resistant filtrate reducer for solid-free drilling fluid with a temperature resistance of 150 ℃, which is prepared from low-viscosity polyanionic cellulose PAC-LV and high-viscosity polyanionic cellulose PAC-HV as main components. For another example, chinese patent application publication No. CN 112521922A discloses a solid-free drilling fluid system in 2021, 3 and 19, wherein the fluid loss additive is sulfonated lignite.
The filtrate reducer applied to the solid-phase-free drilling fluid system also comprises a water-soluble copolymer taking polyacrylamide and 2-acrylamide-2-methylpropanesulfonic acid as monomers. For example, the literature "high temperature resistant solid-free drilling fluid technology" discloses a temperature resistant salt resistant filtrate reducer for solid-free drilling fluid in month 5 of 2017, which is prepared by polymerizing Acrylamide (AM), 2-methyl-2-acrylamidopropane sulfonic Acid (AMPS) and methacryloyloxyethyl trimethyl ammonium chloride (DMC) serving as monomers, wherein the medium pressure filtrate loss of the system after aging at 180 ℃ is 6.2mL, but the high calcium resistant performance is not mentioned.
At present, most of oil fields in China are developed in the middle and later stages, and unused geological reserves are concentrated in high-temperature stratum, so that higher requirements are provided for solid-free drilling fluid with good reservoir protection performance. In particular, the ultra-deep and ultra-deep well of the northern-order oil-gas field in Xinjiang is buried deeply, the depth is generally more than 7000m, the bottom hole temperature can be more than 180 ℃, the drilling fluid density is 1.15-1.80 g/cm 3, the stratum water is calcium stratum water, the calcium ion concentration is up to 15000mg/L, the breaking degree of the Ornithoid reservoir is high, the cementing property is poor, the well wall instability is easy to be induced due to the invasion of free water, and then the research and development of the high molecular polymer with excellent filtration reducing, temperature resisting, salt resisting and calcium resisting performances as the filtration reducing agent of the solid-phase-free drilling fluid is urgently needed, so that the low filtration loss of the system under the high temperature, high salt and calcium environments is ensured. The filtrate reducer disclosed in the above documents and patents has better filtration and temperature resistance, but cannot simultaneously realize salt resistance and calcium resistance, because the salting-out effect of monovalent salt, especially divalent calcium ions, can cause polymer aggregation and precipitation of the filtrate reducer.
Disclosure of Invention
In order to overcome the problems in the prior art, the invention provides a filtrate reducer for drilling fluid, and a preparation method and application thereof. For example, one of the purposes of the invention is to provide a fluid loss additive for drilling fluid, which uses monomers with specific proportion as raw materials, introduces anti-calcium groups, can maximally protect hydration films on the surfaces of molecules from being damaged, and improves salt resistance and calcium resistance. In addition, the molecular weight can be strictly controlled within a proper range, so that the filter cake micropores can be effectively blocked by the fluid loss additive molecules, and the fluid loss effect is improved.
To achieve the above object, the first aspect of the present invention provides a raw material composition for preparing a fluid loss additive for drilling fluids, including a monomer a, a monomer B, a monomer C, a monomer D, and a monomer E. Wherein, the monomer A is selected from monomers with a structure shown in a formula (I);
The monomer B is selected from monomers with a structure shown in a formula (II);
the monomer C is selected from monomers with a structure shown in a formula (III);
the monomer D is selected from monomers with a structure shown in a formula (IV);
The monomer E is selected from monomers with a structure shown in a formula (V),
In formula (I), R 1 is selected from hydrogen, C 1～C5 straight chain alkyl, C 3～C5 branched alkyl, and C 3～C5 cycloalkyl, preferably hydrogen or C 1～C5 straight chain alkyl, more preferably hydrogen, methyl, or ethyl;
In formula (II), R 2 is selected from the group consisting of alkylene of C 1-C6, R 3 and R 4 are the same or different and are each independently selected from the group consisting of hydrogen, C 1～C10 straight chain alkyl, C 3～C10 branched chain alkyl and C 3～C10 cycloalkyl, preferably C 1～C5 straight chain alkyl, more preferably methyl or ethyl;
In formula (III), R 5 and R 6 are the same or different and are each independently selected from hydrogen, C 1～C5 linear alkyl, C 3～C5 branched alkyl and C 3～C5 cycloalkyl, preferably hydrogen or C 1～C5 linear alkyl, more preferably hydrogen, methyl or ethyl;
In formula (IV), R 7 and R 8 are the same or different and are each independently selected from hydrogen, C 1～C5 linear alkyl, C 3～C5 branched alkyl and C 3 to C5 cycloalkyl, preferably hydrogen or C 1～C5 linear alkyl, more preferably hydrogen, methyl or ethyl;
In formula (V), R 9 is selected from hydrogen, C 1～C5 straight chain alkyl and C 3～C5 branched alkyl, preferably hydrogen or methyl, more preferably hydrogen.
According to the invention, in formula (IV), R 7 and R 8 are not simultaneously hydrogen.
In some embodiments of the invention, monomer B is selected from one or more of 2-acrylamido-2-methylpropanesulfonic acid, 2-acrylamido-2-ethylpropanesulfonic acid, and 2-acrylamido-2-methylbutanesulfonic acid; the monomer C is one or more selected from diallyl dimethyl ammonium chloride, diallyl diethyl ammonium chloride and diallyl dipropyl ammonium chloride.
In some embodiments of the present invention, the raw material composition has a content of monomer a of 50 to 97.5 parts by weight, a content of monomer B of 1 to 50 parts by weight, a content of monomer C of 0.1 to 8 parts by weight, a content of monomer D of 0.01 to 1 part by weight, and a content of monomer E of 0.001 to 2 parts by weight;
Preferably, the content of the monomer A is 50 to 80 parts by weight, the content of the monomer B is 15 to 45 parts by weight, the content of the monomer C is 1 to 4 parts by weight, the content of the monomer D is 0.1 to 0.7 part by weight, and the content of the monomer E is 0.1 to 0.5 part by weight.
In a second aspect, the present invention provides a polymer obtainable from the feedstock composition according to the first aspect of the invention, said polymer having a viscosity average molecular weight of from 50 to 300, preferably from 100 to 200.
The third aspect of the invention provides a method for preparing a filtrate reducer for drilling fluid, comprising the following steps: a feed system comprising a feed composition according to the first aspect of the invention and a solvent is polymerized to form a fluid loss additive.
In some embodiments of the invention, the solvent is water, preferably the mass fraction of the feedstock composition in the feedstock system is 10% to 50%, preferably 15% to 40%, more preferably 20% to 30%.
In some embodiments of the present invention, the solvent is present in the feed system in an amount of 50% to 90% by mass, preferably 60% to 85% by mass, and more preferably 70% to 80% by mass.
In some embodiments of the invention, the pH of the feed system is in the range of 4 to 12, preferably 5 to 10, more preferably 6 to 9, preferably the pH of the feed system is adjusted by an inorganic base selected from one or more of sodium hydroxide, potassium hydroxide and sodium carbonate, preferably sodium hydroxide.
In some embodiments of the present invention, a chain transfer agent may also be included in the feed system, preferably the chain transfer agent is selected from one or more of sodium formate, sodium hypophosphite, isopropanol, mercaptoethanol, mercaptoacetic acid, mercaptopropanol, and mercaptopropionic acid, preferably one or more of sodium formate and isopropanol, more preferably sodium formate. Wherein the addition amount of the chain transfer agent is 0.1-5% of the mass of the raw material composition, and preferably 1-3%.
In some embodiments of the present invention, an initiator is further included in the feed system, preferably the initiator is one of a redox-type initiator or an azo-type initiator, preferably an azo-type initiator. Wherein the addition amount of the azo initiator is 0.002-0.3% of the mass of the raw material composition, and preferably 0.01-0.1%. Wherein the azo initiator is selected from one or more of azodiisobutyronitrile, azodiimidazolyl propane dihydrochloride, 4' -azobis (4-cyanovaleric acid) and 2,2' -azodiisobutyl amidine hydrochloride, preferably one or more of 2,2' -azodiisobutyl amidine hydrochloride and azodiimidazolyl propane dihydrochloride.
In some embodiments of the invention, the polymerization conditions include: the temperature is between 10 ℃ below zero and 80 ℃ below zero for 1 to 20 hours; preferably, the temperature is 20-70 ℃ and the time is 2-10 hours; more preferably, the temperature is 40 to 60℃and the time is 3 to 6 hours. Here, for example, the polymerization reaction conditions are that after the raw material system comprising the raw material composition, the solvent, the chain transfer agent and the initiator is deoxygenated (for example, deoxygenated by introducing nitrogen), the reaction is carried out at 40℃to 60℃for 3 to 6 hours, and the reaction is completed.
In some embodiments of the present invention, after the polymerization reaction is completed, the obtained product may further include granulating, drying, pulverizing, and sieving.
The method and conditions for granulation are not particularly limited in the present invention, and a person skilled in the art can select an appropriate process according to the particle size of the target product.
The method has no special requirements on the drying method and conditions, and preferably, a fluidized bed drying method can be adopted, wherein the temperature of the fluidized bed drying is 60-90 ℃, preferably 75-85 ℃; the drying time is 0.2 to 4 hours, preferably 0.5 to 2 hours.
The method and conditions for pulverization are not particularly limited in the present invention, and those skilled in the art can select an appropriate process according to the particle size of the target product.
The method and conditions of the screening are not particularly limited in the present invention, and a person skilled in the art can select an appropriate process according to the particle size of the target product.
In some embodiments of the present invention, a method of preparing a fluid loss additive for a drilling fluid may include the steps of:
S1, providing a first reaction solution containing the raw material composition and the solvent;
s2, regulating the pH value of the first reaction solution through the inorganic alkaline matter to obtain a second reaction solution;
s3, carrying out deoxidization treatment on the second reaction solution to obtain a third reaction solution;
S4, adding the chain transfer agent into the third reaction solution to obtain a fourth reaction solution;
S5, heating the fourth reaction solution to the target temperature, and then adding an initiator to initiate polymerization reaction to obtain the filtrate reducer.
According to the present invention, in the step S1, the mass percentage of the raw material monomer in the first reaction solution is 15% to 40%, preferably 20% to 30%.
According to the present invention, in the step S1, the mass percentage of the solvent in the first reaction solution is 60% to 85%, preferably 70% to 80%.
According to the invention, in step S2, the pH of the second reaction solution is 5 to 10, preferably 6 to 9.
According to the present invention, in step S2, the temperature of the second reaction solution is controlled to be 0 ℃ to 20 ℃.
According to the present invention, in step S4, the method of the oxygen removal treatment includes introducing an inert gas into the third reaction solution to perform sufficient oxygen removal (for example, for 0.5 to 2 hours).
According to the invention, in step S5, the target temperature is 20-70 ℃, preferably 40-60 ℃.
In some embodiments of the present invention, a method of preparing a fluid loss additive for a drilling fluid may include the steps of:
(1) Mixing acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, diallyl dimethyl ammonium chloride, N-dimethylacrylamide and 2-acryloyloxy-1, 2, 3-tricarboxyl propane with deionized water to prepare a solution with the mass fraction of raw material monomers of 20-30%, controlling the temperature of the solution to 0-20 ℃, and regulating the pH to 4-12 (preferably 6-9) by using an inorganic alkaline compound to obtain a monomer mixture solution;
(2) Pumping the monomer mixed solution obtained in the step (1) into a polymerization kettle, adding a chain transfer agent such as sodium formate, introducing high-purity nitrogen to remove oxygen (the introducing time is 0.5-2 hours), heating to 60 ℃, adding an azo initiator such as 2,2' -azobisisobutylaminidine hydrochloride, and reacting for 1-10 hours (preferably 3-6 hours) to obtain copolymer gel blocks;
(3) Granulating the copolymer gel block obtained in the step (2) into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 0.2-4 hours by a fluidized bed under the condition of hot air with the temperature of 40-110 ℃, and crushing and screening to obtain the filtrate reducer.
According to a fourth aspect of the invention, there is provided a fluid loss additive for drilling fluids prepared by the method according to the third aspect of the invention.
In some embodiments of the invention, the viscosity average molecular weight of the fluid loss additive for drilling fluids is 50 to 300 tens of thousands, preferably 100 to 200 tens of thousands. For example, the viscosity average molecular weight of the fluid loss additive for drilling fluids can be measured by the black-matrix viscometer method at 25 ℃.
In a fifth aspect the present invention provides the use of a polymer according to the second aspect of the present invention or a fluid loss additive according to the fourth aspect of the present invention in a drilling fluid, in particular as a fluid loss additive.
According to the invention, the dosage of the filtrate reducer is 5-30 g/L based on the total mass of the drilling fluid.
For example, the viscosity average molecular weight of the filtrate reducer is 100-200 ten thousand, the filtrate reducer with the mass fraction of 2% is added into the 3 formate-based slurry (containing 15000g/mLCa 2+) with the viscosity average molecular weight of 1.45g/cm, and the API filtrate reducer after aging for 16 hours at 180 ℃ is 8.4mL, which shows that the filtrate reducer has good temperature resistance and calcium resistance, and can effectively improve the filtration wall forming performance of solid-free drilling fluid under high temperature and high calcium environments.
Compared with the prior art, the invention has at least one of the following beneficial effects:
1) The filtrate reducer of the invention introduces the anti-calcium group, so as to furthest protect the hydration film on the surface of the molecule from being damaged, improve the salt resistance and calcium efficiency, and strictly control the molecular weight in a proper range, thereby ensuring that the filtrate reducer molecule can effectively block the micro-pores of the filter cake and improve the filtrate reducing effect;
2) According to the invention, a supermolecule chemical theory is introduced, and a reversible and stable three-dimensional space network structure is formed by utilizing the supermolecule induction effect between salt ions in formate brine and zwitterionic functional groups on a molecular chain of the filtrate reducer, so that the temperature resistance and the calcium resistance are obviously improved;
3) The monomer with weak hydrophobic effect is introduced into the raw materials of the filtrate reducer, so that the temperature resistance and salt resistance can be further improved; five-membered heterocyclic monomer is also introduced, so that the molecular rigidity is improved, the molecular volume is prevented from being reduced due to excessive shrinkage of a molecular chain, and the blocking effect is improved;
4) The fluid loss additive is polymerized into a five-membered polymer through the monomer A, the monomer B, the monomer C, the monomer D and the monomer E, and can achieve better fluid loss, temperature resistance and calcium resistance effects when used for the fluid loss additive of solid-phase-free drilling fluid. Wherein, the monomer A is the main structure of the five-membered polymer, and can provide the proper length of the molecular chain of the five-membered polymer; the monomer B with the sulfonic acid group can provide better temperature resistance and salt resistance; the monomer D with weak hydrophobic effect can further improve the temperature resistance and salt and calcium resistance of the polymer; the monomer E has a multi-carboxyl functional group, and can improve the calcium resistance of the polymer through chelation with calcium ions; in addition, the monomer A and the monomer B have negative charges, the monomer C has positive charges, and a stable three-dimensional grid structure can be formed through electrostatic induction between the monomer A and the monomer B and between the monomer C and salt calcium ions, so that the temperature resistance and the salt calcium resistance are obviously improved;
5) The invention can use azo initiation system to initiate five monomers with temperature resistance, calcium resistance, static induction, hydrophobic and chelating effects to carry out aqueous solution free radical polymerization, and then carry out granulation, drying, crushing and screening to obtain the filtrate reducer.
Detailed Description
The present invention will be described in detail with reference to examples, but the scope of the present invention is not limited to the following description.
The specific conditions are not noted in the examples and are carried out according to conventional conditions or conditions recommended by the manufacturer. The reagents or apparatus used were conventional products available commercially without the manufacturer's knowledge.
Example 1
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyl dimethyl ammonium chloride, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxyl propane and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 9 under the stirring state, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A1.
Example 2
1000 Kg (14.1 kmol) of acrylamide, 900 kg (4.34 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 80 kg (0.49 kmol) of diallyl dimethyl ammonium chloride, 2 kg (0.02 kmol) of N, N-dimethylacrylamide, 2 kg (0.02 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxyl propane and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 9 under the stirring state, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A2.
Example 3
1800 Kg (25.3 kmol) of acrylamide, 100 kg (0.48 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 20 kg (0.12 kmol) of diallyl dimethyl ammonium chloride, 14 kg (0.14 kmol) of N, N-dimethylacrylamide, 10 kg (0.09 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxyl propane and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 9 under the stirring state, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A3.
Example 4
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyl dimethyl ammonium chloride, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxyl propane and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 7 under the stirring state, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A4.
Example 5
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyl dimethyl ammonium chloride, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxyl propane and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 9 under the stirring state, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 80 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel block by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A5.
Example 6
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyldimethylammonium chloride, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxypropane and 8000 kg of deionized water are charged into a batch kettle. Controlling the temperature of the solution to be 5 ℃, and adding sodium hydroxide to adjust the pH to 9 under the stirring state to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 100 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A6.
Example 7
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyldimethylammonium chloride, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxypropane and 8000 kg of deionized water are charged into a batch kettle. Controlling the temperature of the solution to be 5 ℃, and adding sodium hydroxide to adjust the pH to 9 under the stirring state to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 0.2 kg of 2,2' -azobisisobutylaminidine hydrochloride, and standing for polymerization for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A7.
Example 8
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyldimethylammonium chloride, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxypropane and 8000 kg of deionized water are charged into a batch kettle. Controlling the temperature of the solution to be 5 ℃, and adding sodium hydroxide to adjust the pH to 9 under the stirring state to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 6h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer A8.
Example 9
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyldimethylammonium chloride, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxypropane and 8000 kg of deionized water are charged into a batch kettle. While stirring, sodium hydroxide was added to adjust the pH to 9 to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of hot air with the temperature of 95 ℃, and obtaining 20-80 meshes of filtrate reducer A9 by crushing and screening.
Example 10
Example 10 is essentially the same as example 1 except that 2-acrylamido-2-methylpropanesulfonic acid in example 1 is replaced with 2-acrylamido-2-ethylpropanesulfonic acid. Under other conditions, a filtrate reducer A10 was prepared.
Example 11
Example 11 is essentially the same as example 1 except that N, N-dimethylacrylamide is used instead of N, N-dimethylacrylamide in example 1. Under other conditions, a filtrate reducer A11 was produced.
Example 12
Example 12 is essentially the same as example 1 except that N, N-diethylacrylamide is used in place of N, N-dimethylacrylamide in example 1. Under other conditions, fluid loss additive A12 was prepared.
Example 13
Example 13 was substantially the same as example 1 except that 2-acryloyloxy-1, 2, 3-tricarboxypropane in example 1 was replaced with 2-methacryloyloxy-1, 2, 3-tricarboxypropane. Under other conditions, a filtrate reducer A13 was produced.
Comparative example 1
1300 Kg (18.3 kmol) of acrylamide, 620 kg (2.99 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 80 kg (0.49 kmol) of dimethyldiallylammonium chloride and 8000 kg of deionized water were charged into a batch kettle. While stirring, sodium hydroxide was added to adjust the pH to 9 to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel block by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of hot air with the temperature of 95 ℃, and crushing and screening to obtain the comparative example B1 with the size of 20-80 meshes.
Comparative example 2
1350 Kg (19.0 kmol) of acrylamide, 650 kg (3.14 kmol) of 2-acrylamido-2-methylpropanesulfonic acid and 8000 kg of deionized water were added to a batch reactor, and sodium hydroxide was added to adjust the pH to 9 while stirring, to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel block by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of hot air with the temperature of 95 ℃, and crushing and screening to obtain the comparative example B2 with the size of 20-80 meshes.
Comparative example 3
Polyanionic cellulose filtrate reducer produced by Chevron PHILLIPS CHEMICAL, chevron Phillips chemical industry CoAs comparative example B3.
Comparative example 4
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 8 kg (0.08 kmol) of N, N-dimethylacrylamide, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxypropane and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 9 under the stirring state, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer B4.
Comparative example 5
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyl dimethyl ammonium chloride, 6 kg (0.05 kmol) of 2-acryloyloxy-1, 2, 3-tricarboxyl propane and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 9 under stirring, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer B5.
Comparative example 6
1300 Kg (18.3 kmol) of acrylamide, 600 kg (2.89 kmol) of 2-acrylamido-2-methylpropanesulfonic acid, 50 kg (0.31 kmol) of diallyl dimethyl ammonium chloride, 8 kg (0.08 kmol) of N, N-dimethyl acrylamide and 8000 kg of deionized water are added into a batching kettle, the temperature of the solution is controlled to be 5 ℃, and sodium hydroxide is added to adjust the pH to 9 under the stirring state, so as to obtain a monomer solution. Pumping the monomer solution into a polymerization kettle, introducing high-purity nitrogen to deoxidize for 0.5h, heating to 60 ℃, sequentially adding 60 kg of sodium formate and 2 kg of 2,2' -azobisisobutylaminidine hydrochloride, standing and polymerizing for 4h to obtain copolymer gel. Opening a ball valve at the bottom of the polymerization kettle, extruding the obtained copolymer gel blocks by using 0.3MPa compressed air, granulating into small colloidal particles with the diameter of 4-6 mm by a granulator, drying for 2 hours under the condition of 75 ℃ hot air, and crushing and screening to obtain the 20-80-mesh filtrate reducer B6.
Test example 1
The viscosity average molecular weight of the polymer was calculated according to the method specified in GB12005.10-92 using the formula m= ([ η ]/K) 1/α, where k=4.75×10 -3, α=0.80, [ η ] is the intrinsic viscosity.
The measurement results are shown in table 1.
As is clear from Table 1, the viscosity average molecular weight of the fluid loss additives A1 to A13 of the present invention is 108 to 188 thousands, and the viscosity average molecular weight of the fluid loss additives of comparative examples B1 to B6 (excluding comparative example B3) is 173 to 456 thousands, indicating that the addition of the monomers C, D and E can reduce the viscosity average molecular weight of the copolymer.
Test example 2
350ML of deionized water was weighed into a high-speed stirring cup, and 573g of potassium formate was added thereto to prepare an aqueous potassium formate solution having a density of 1.45g/cm 3.
350ML of potassium formate aqueous solution is measured, 1.75g of anhydrous sodium carbonate and 3.5g of sodium bicarbonate are added under stirring, 1.05g of xanthan gum is slowly added after stirring at high speed for 10min, at least two times of stirring are stopped, powder adhered to the container wall is scraped, and sealing maintenance is performed for 24h at 25+/-3 ℃ to obtain solid-free drilling fluid base slurry.
Taking 350mL of prepared 12 parts of solid-free drilling fluid base slurry, respectively slowly adding 7g of filtrate reducer A1-A13 and comparative examples B1-B8 under stirring, stirring for 30min by using an electric stirrer, adding 14g of anhydrous calcium chloride, continuously stirring and dissolving for 20min, rolling for 16h at a constant temperature of 180 ℃ in a high-temperature roller furnace, cooling, and then stirring for 5min, thereby measuring the API filtrate loss FL. API fluid loss measurements were performed as specified in GB/T16783.1.
The measurement results are shown in table 2.
As can be seen from Table 2, the calcium-containing solid-free formate drilling fluid added with the filtrate reducer A1-A13 of the invention has the API filtrate loss of 8.4-12.8 mL after aging at 180 ℃ and is superior to the existing foreign similar products(I.e., comparative example B3), the five-membered copolymer has better filtration loss performance, temperature resistance and salt-calcium resistance, and can effectively improve the filtration loss wall-forming performance of the solid-free drilling fluid in a high-temperature and high-calcium environment; the calcium-containing solid-free formate drilling fluid added in comparative examples B1 to B6 (except comparative example B3) has an API filtrate loss of 12.5 to 26.5mL after high-temperature aging at 180 ℃ and shows that the added monomers C, D and E can remarkably improve the temperature resistance and the salt-calcium resistance of the copolymer, and the relatively higher molecular weight can reduce the filtrate loss effect.
It is noted that the above-described embodiments are only for explaining the present invention, and do not constitute any limitation of the present invention. The invention has been described with reference to exemplary embodiments, but it is understood that the words which have been used are words of description and illustration, rather than words of limitation. Modifications may be made to the invention as defined in the appended claims, and the invention may be modified without departing from the scope and spirit of the invention. Although the invention is described herein with reference to particular means, materials and embodiments, the invention is not intended to be limited to the particulars disclosed herein, as the invention extends to all other means and applications which perform the same function.
Claims (30)
1. A raw material composition for preparing a filtrate reducer for drilling fluid comprises a monomer A, a monomer B, a monomer C, a monomer D and a monomer E,
Wherein, the monomer A is selected from monomers with a structure shown in a formula (I);
Formula (I)
The monomer B is selected from monomers with a structure shown in a formula (II);
Formula (II)
The monomer C is selected from monomers with a structure shown in a formula (III);
Formula (III)
The monomer D is selected from monomers with a structure shown in a formula (IV);
(IV)
The monomer E is selected from monomers with a structure shown in a formula (V),
(V)
In formula (I), R 1 is selected from hydrogen, C 1~C5 straight chain alkyl, C 3~C5 branched alkyl, and C 3~C5 cycloalkyl;
In formula (II), R 2 is selected from the group consisting of alkylene of C 1-C6, R 3 and R 4 are the same or different and are each independently selected from the group consisting of hydrogen, C 1~C10 straight chain alkyl, C 3~C10 branched alkyl and C 3~C10 cycloalkyl;
In formula (III), R 5 and R 6 are the same or different and are each independently selected from hydrogen, C 1~C5 straight-chain alkyl, C 3~C5 branched alkyl, and C 3~C5 cycloalkyl;
In formula (IV), R 7 and R 8 are the same or different and are each independently selected from hydrogen, C 1~C5 straight-chain alkyl, C 3~C5 branched alkyl, and C 3~C5 cycloalkyl;
In formula (V), R 9 is selected from hydrogen, C 1~C5 straight chain alkyl, and C 3~C5 branched alkyl;
In the raw material composition, the content of the monomer A is 50-97.5 parts by weight, the content of the monomer B is 1-50 parts by weight, the content of the monomer C is 0.1-8 parts by weight, the content of the monomer D is 0.01-1 part by weight, and the content of the monomer E is 0.001-2 parts by weight;
The viscosity average molecular weight of the polymer prepared from the raw material composition is 50-300 ten thousand.
2. The feedstock composition according to claim 1, wherein in formula (I), R 1 is hydrogen or C 1~C5 straight chain alkyl; and/or
In formula (II), R 2 is C 1~C5 straight-chain alkyl; and/or the number of the groups of groups,
In formula (III), R 5 and R 6 are hydrogen or C 1~C5 linear alkyl; and/or the number of the groups of groups,
In formula (IV), R 7 and R 8 are hydrogen or C 1~C5 linear alkyl; and/or the number of the groups of groups,
In formula (V), R 9 is hydrogen or methyl.
3. The feedstock composition according to claim 2, wherein in formula (I), R1 is hydrogen, methyl or ethyl; and/or the number of the groups of groups,
In the formula (II), R 2 is methyl or ethyl; and/or the number of the groups of groups,
In formula (III), R 5 and R 6 are hydrogen, methyl or ethyl; and/or the number of the groups of groups,
In formula (IV), R 7 and R 8 are hydrogen, methyl or ethyl; and/or the number of the groups of groups,
In formula (V), R 9 is hydrogen.
4. The raw material composition according to any one of claims 1 to 3, wherein the content of the monomer a is 50 to 80 parts by weight, the content of the monomer B is 15 to 45 parts by weight, the content of the monomer C is 1 to 4 parts by weight, the content of the monomer D is 0.1 to 0.7 part by weight, and the content of the monomer E is 0.1 to 0.5 part by weight.
5. A feedstock composition according to any one of claims 1 to 3, wherein the polymer produced from the feedstock composition has a viscosity average molecular weight of 100 to 200 tens of thousands.
6. The preparation method of the filtrate reducer for the drilling fluid is characterized by comprising the following steps:
Polymerizing a feed system comprising the feed composition of any one of claims 1-5 and a solvent to produce a fluid loss additive.
7. The method for producing a fluid loss additive for drilling fluids according to claim 6, wherein the solvent is water.
8. The method for producing a fluid loss additive for drilling fluids according to claim 7, wherein the mass fraction of the raw material composition in the raw material system is 10% -50%.
9. The method for preparing a fluid loss additive for drilling fluids according to claim 8, wherein the mass fraction of the raw material composition is 15% -40%.
10. The method for preparing a fluid loss additive for drilling fluids according to claim 9, wherein the mass fraction of the raw material composition is 20% -30%.
11. The method for producing a fluid loss additive for drilling fluids according to any one of claims 6 to 10, wherein the pH of the raw material system is controlled to be 4 to 12 and/or is adjusted by an inorganic alkaline substance.
12. The method for producing a fluid loss additive for drilling fluids according to claim 11, wherein the pH of the raw material system is controlled to be 5 to 10, and/or the inorganic alkaline substance is one or more selected from sodium hydroxide, potassium hydroxide and sodium carbonate.
13. The method for producing a fluid loss additive for drilling fluids according to claim 12, wherein the pH of the raw material system is controlled to be 6 to 9, and/or the inorganic alkaline substance is sodium hydroxide.
14. The method for producing a fluid loss additive for drilling fluids according to any one of claims 6 to 10, wherein a chain transfer agent is further included in the raw material system.
15. The method for producing a fluid loss additive for drilling fluids according to claim 14, wherein the chain transfer agent is one or more selected from sodium formate, sodium hypophosphite, isopropyl alcohol, mercaptoethanol, mercaptoacetic acid, mercaptopropanol and mercaptopropionic acid, and/or the addition amount of the chain transfer agent is 0.1% -5% by mass of the raw material composition.
16. The method for producing a fluid loss additive for drilling fluids according to claim 15, wherein the chain transfer agent is one or more of sodium formate and isopropyl alcohol; and/or the addition amount of the chain transfer agent is 1% -3% of the mass of the raw material composition.
17. The method for producing a fluid loss additive for drilling fluids according to claim 16, wherein the chain transfer agent is sodium formate.
18. The method for preparing a fluid loss additive for drilling fluids according to any one of claims 6-10, wherein the feed system further comprises an initiator.
19. The method for producing a fluid loss additive for drilling fluids according to claim 18, wherein the initiator is one of a redox initiator and an azo initiator, and/or the azo initiator is added in an amount of 0.002% -0.3% by mass of the raw material composition.
20. The method for producing a fluid loss additive for drilling fluids according to claim 19, wherein the fluid loss additive is an azo initiator; and/or the addition amount of the azo initiator is 0.01% -0.1% of the mass of the raw material composition.
21. The method for preparing a fluid loss additive for drilling fluids according to claim 20, wherein the azo initiator is selected from one or more of azobisisobutyronitrile, azobisimidazolinylpropane dihydrochloride, 4 '-azobis (4-cyanovaleric acid) and 2,2' -azobisisobutylamidine hydrochloride.
22. The method for producing a fluid loss additive for drilling fluids according to claim 21, wherein the azo initiator is one or more of 2,2' -azobisisobutylamidine hydrochloride and azobisimidazoline propane dihydrochloride.
23. The method for preparing a fluid loss additive for drilling fluids according to any one of claims 6 to 10, wherein the polymerization reaction conditions include: the temperature is-10 ℃ to 80 ℃ and the time is 1 to 20 hours.
24. The method for preparing a fluid loss additive for drilling fluid according to claim 23, wherein the temperature is 20-70 ℃ and the time is 2-10 hours.
25. The method for preparing a fluid loss additive for drilling fluid according to claim 24, wherein the temperature is 40-60 ℃ and the time is 3-6 hours.
26. A fluid loss additive for drilling fluids, which is prepared by the method for preparing the fluid loss additive for drilling fluids according to any one of claims 6 to 25.
27. The fluid loss additive for drilling fluids according to claim 26, wherein the viscosity average molecular weight of the fluid loss additive for drilling fluids is 50 to 300 tens of thousands.
28. The fluid loss additive for drilling fluids according to claim 27, wherein the viscosity average molecular weight of the fluid loss additive for drilling fluids is 100 to 200 tens of thousands.
29. The use of a fluid loss additive for drilling fluids according to any one of claims 26 to 28 in drilling fluids.
30. The use according to claim 29, as a fluid loss additive.
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