CN108913118A - One kind being used for high water-cut reservoir water-control oil-increasing acidification technique method - Google Patents
One kind being used for high water-cut reservoir water-control oil-increasing acidification technique method Download PDFInfo
- Publication number
- CN108913118A CN108913118A CN201810620657.6A CN201810620657A CN108913118A CN 108913118 A CN108913118 A CN 108913118A CN 201810620657 A CN201810620657 A CN 201810620657A CN 108913118 A CN108913118 A CN 108913118A
- Authority
- CN
- China
- Prior art keywords
- water
- oil
- acid
- increasing
- treatment fluid
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 230000020477 pH reduction Effects 0.000 title claims abstract description 45
- 238000000034 method Methods 0.000 title claims abstract description 32
- 239000012530 fluid Substances 0.000 claims abstract description 55
- 239000002253 acid Substances 0.000 claims abstract description 54
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 39
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 32
- 239000000654 additive Substances 0.000 claims abstract description 22
- 230000000996 additive effect Effects 0.000 claims abstract description 22
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims abstract description 10
- 239000002562 thickening agent Substances 0.000 claims abstract description 9
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims abstract description 5
- 239000005011 phenolic resin Substances 0.000 claims abstract description 5
- 229920001568 phenolic resin Polymers 0.000 claims abstract description 5
- 239000001103 potassium chloride Substances 0.000 claims abstract description 5
- 235000011164 potassium chloride Nutrition 0.000 claims abstract description 5
- 239000003921 oil Substances 0.000 claims description 67
- 238000005260 corrosion Methods 0.000 claims description 21
- 230000007797 corrosion Effects 0.000 claims description 21
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 20
- -1 iron ion Chemical class 0.000 claims description 19
- 239000004927 clay Substances 0.000 claims description 18
- 239000003381 stabilizer Substances 0.000 claims description 17
- 238000006073 displacement reaction Methods 0.000 claims description 15
- 239000000080 wetting agent Substances 0.000 claims description 14
- 238000011084 recovery Methods 0.000 claims description 12
- 239000004094 surface-active agent Substances 0.000 claims description 12
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 claims description 11
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical group FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 claims description 8
- 230000035699 permeability Effects 0.000 claims description 8
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 claims description 6
- MUBZPKHOEPUJKR-UHFFFAOYSA-N Oxalic acid Chemical compound OC(=O)C(O)=O MUBZPKHOEPUJKR-UHFFFAOYSA-N 0.000 claims description 6
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 claims description 6
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 6
- 239000012459 cleaning agent Substances 0.000 claims description 6
- 229920003171 Poly (ethylene oxide) Polymers 0.000 claims description 5
- 230000015572 biosynthetic process Effects 0.000 claims description 5
- 239000007788 liquid Substances 0.000 claims description 5
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 4
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 4
- 239000000194 fatty acid Substances 0.000 claims description 4
- 229930195729 fatty acid Natural products 0.000 claims description 4
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 4
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 4
- 239000011148 porous material Substances 0.000 claims description 4
- 125000005211 alkyl trimethyl ammonium group Chemical group 0.000 claims description 3
- 150000002191 fatty alcohols Chemical class 0.000 claims description 3
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims description 3
- 229910052742 iron Inorganic materials 0.000 claims description 3
- 150000003222 pyridines Chemical class 0.000 claims description 3
- 239000011435 rock Substances 0.000 claims description 3
- 150000003839 salts Chemical class 0.000 claims description 3
- RSWGJHLUYNHPMX-UHFFFAOYSA-N Abietic-Saeure Natural products C12CCC(C(C)C)=CC2=CCC2C1(C)CCCC2(C)C(O)=O RSWGJHLUYNHPMX-UHFFFAOYSA-N 0.000 claims description 2
- 239000004215 Carbon black (E152) Substances 0.000 claims description 2
- ZGTMUACCHSMWAC-UHFFFAOYSA-L EDTA disodium salt (anhydrous) Chemical compound [Na+].[Na+].OC(=O)CN(CC([O-])=O)CCN(CC(O)=O)CC([O-])=O ZGTMUACCHSMWAC-UHFFFAOYSA-L 0.000 claims description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 2
- KHPCPRHQVVSZAH-HUOMCSJISA-N Rosin Natural products O(C/C=C/c1ccccc1)[C@H]1[C@H](O)[C@@H](O)[C@@H](O)[C@@H](CO)O1 KHPCPRHQVVSZAH-HUOMCSJISA-N 0.000 claims description 2
- 229960000583 acetic acid Drugs 0.000 claims description 2
- 150000001412 amines Chemical class 0.000 claims description 2
- 125000005587 carbonate group Chemical group 0.000 claims description 2
- 229940124274 edetate disodium Drugs 0.000 claims description 2
- 239000012362 glacial acetic acid Substances 0.000 claims description 2
- 229910052736 halogen Inorganic materials 0.000 claims description 2
- 229930195733 hydrocarbon Natural products 0.000 claims description 2
- 150000002430 hydrocarbons Chemical class 0.000 claims description 2
- 239000000203 mixture Substances 0.000 claims description 2
- 238000011017 operating method Methods 0.000 claims description 2
- 235000006408 oxalic acid Nutrition 0.000 claims description 2
- 229920000642 polymer Polymers 0.000 claims description 2
- 150000003242 quaternary ammonium salts Chemical class 0.000 claims description 2
- KHPCPRHQVVSZAH-UHFFFAOYSA-N trans-cinnamyl beta-D-glucopyranoside Natural products OC1C(O)C(O)C(CO)OC1OCC=CC1=CC=CC=C1 KHPCPRHQVVSZAH-UHFFFAOYSA-N 0.000 claims description 2
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims 1
- ULUAUXLGCMPNKK-UHFFFAOYSA-N Sulfobutanedioic acid Chemical class OC(=O)CC(C(O)=O)S(O)(=O)=O ULUAUXLGCMPNKK-UHFFFAOYSA-N 0.000 claims 1
- QYKIQEUNHZKYBP-UHFFFAOYSA-N Vinyl ether Chemical compound C=COC=C QYKIQEUNHZKYBP-UHFFFAOYSA-N 0.000 claims 1
- DHNCFAWJNPJGHS-UHFFFAOYSA-J [C+4].[O-]C([O-])=O.[O-]C([O-])=O Chemical compound [C+4].[O-]C([O-])=O.[O-]C([O-])=O DHNCFAWJNPJGHS-UHFFFAOYSA-J 0.000 claims 1
- 239000002280 amphoteric surfactant Substances 0.000 claims 1
- VKFAUCPBMAGVRG-UHFFFAOYSA-N dipivefrin hydrochloride Chemical compound [Cl-].C[NH2+]CC(O)C1=CC=C(OC(=O)C(C)(C)C)C(OC(=O)C(C)(C)C)=C1 VKFAUCPBMAGVRG-UHFFFAOYSA-N 0.000 claims 1
- LRMHFDNWKCSEQU-UHFFFAOYSA-N ethoxyethane;phenol Chemical compound CCOCC.OC1=CC=CC=C1 LRMHFDNWKCSEQU-UHFFFAOYSA-N 0.000 claims 1
- MTNDZQHUAFNZQY-UHFFFAOYSA-N imidazoline Chemical group C1CN=CN1 MTNDZQHUAFNZQY-UHFFFAOYSA-N 0.000 claims 1
- JEIPFZHSYJVQDO-UHFFFAOYSA-N iron(III) oxide Inorganic materials O=[Fe]O[Fe]=O JEIPFZHSYJVQDO-UHFFFAOYSA-N 0.000 claims 1
- IIACRCGMVDHOTQ-UHFFFAOYSA-N sulfamic acid Chemical class NS(O)(=O)=O IIACRCGMVDHOTQ-UHFFFAOYSA-N 0.000 claims 1
- 230000000694 effects Effects 0.000 abstract description 9
- 239000003129 oil well Substances 0.000 abstract description 7
- 230000000638 stimulation Effects 0.000 abstract description 7
- 238000011161 development Methods 0.000 abstract description 4
- 230000008901 benefit Effects 0.000 abstract description 3
- 230000008569 process Effects 0.000 abstract description 2
- 239000000243 solution Substances 0.000 description 14
- 238000004519 manufacturing process Methods 0.000 description 13
- 238000010276 construction Methods 0.000 description 6
- 238000002347 injection Methods 0.000 description 5
- 239000007924 injection Substances 0.000 description 5
- 239000010779 crude oil Substances 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 4
- 239000003093 cationic surfactant Substances 0.000 description 3
- 150000008379 phenol ethers Chemical group 0.000 description 3
- 229920002401 polyacrylamide Polymers 0.000 description 3
- 241000191291 Abies alba Species 0.000 description 2
- 208000010392 Bone Fractures Diseases 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 2
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 2
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical group OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 description 2
- 206010017076 Fracture Diseases 0.000 description 2
- 235000019738 Limestone Nutrition 0.000 description 2
- 229920000289 Polyquaternium Polymers 0.000 description 2
- KAESVJOAVNADME-UHFFFAOYSA-N Pyrrole Chemical compound C=1C=CNC=1 KAESVJOAVNADME-UHFFFAOYSA-N 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 2
- 239000003153 chemical reaction reagent Substances 0.000 description 2
- 239000004519 grease Substances 0.000 description 2
- 239000011440 grout Substances 0.000 description 2
- 239000006028 limestone Substances 0.000 description 2
- 239000006210 lotion Substances 0.000 description 2
- 238000012797 qualification Methods 0.000 description 2
- 159000000000 sodium salts Chemical class 0.000 description 2
- 230000009466 transformation Effects 0.000 description 2
- DNIAPMSPPWPWGF-GSVOUGTGSA-N (R)-(-)-Propylene glycol Chemical compound C[C@@H](O)CO DNIAPMSPPWPWGF-GSVOUGTGSA-N 0.000 description 1
- YCKRFDGAMUMZLT-UHFFFAOYSA-N Fluorine atom Chemical compound [F] YCKRFDGAMUMZLT-UHFFFAOYSA-N 0.000 description 1
- 238000010306 acid treatment Methods 0.000 description 1
- 238000005275 alloying Methods 0.000 description 1
- 230000000035 biogenic effect Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000002512 chemotherapy Methods 0.000 description 1
- 239000012141 concentrate Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 150000004665 fatty acids Chemical class 0.000 description 1
- 229910052731 fluorine Inorganic materials 0.000 description 1
- 239000011737 fluorine Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 239000003292 glue Substances 0.000 description 1
- 150000002431 hydrogen Chemical class 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 229940116315 oxalic acid Drugs 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000001681 protective effect Effects 0.000 description 1
- JUJWROOIHBZHMG-UHFFFAOYSA-N pyridine Substances C1=CC=NC=C1 JUJWROOIHBZHMG-UHFFFAOYSA-N 0.000 description 1
- UMJSCPRVCHMLSP-UHFFFAOYSA-N pyridine Natural products COC1=CC=CN=C1 UMJSCPRVCHMLSP-UHFFFAOYSA-N 0.000 description 1
- 241000894007 species Species 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/72—Eroding chemicals, e.g. acids
- C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
-
- 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
- C09K8/72—Eroding chemicals, e.g. acids
- C09K8/725—Compositions containing polymers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Lubricants (AREA)
- Detergent Compositions (AREA)
Abstract
The present invention provides one kind to be used for high water-cut reservoir water-control oil-increasing acidification technique method, is successively handled using treatment fluid, main body acid solution, treatment fluid, water-control oil-increasing agent, treatment fluid, main body acid solution, treatment fluid reservoir to be processed；The water-control oil-increasing agent, the component including following mass fraction, 2%-3% potassium chloride, 0.1%-0.5% thickener, 1%-10% oil-soluble phenolic resin, 2%-3% pressure break cleanup additive, remaining is water, and the sum of mass fraction of each component is 100%.Present invention process was both safe and reliable, increased well oil output while controlling water ratio in oil well, improved well stimulation effect, improved producing well development benefit.
Description
Technical field
The invention belongs to technical field of petroleum extraction, are acidified work for high water-cut reservoir water-control oil-increasing more particularly, to one kind
Process.
Background technique
With deepening continuously for domestic each oil field development, water ratio in oil well is gradually risen, the village Dagang Oilfield Wang Xu, discrimination south,
The oil-field aqueous such as officials of feudal dynasties village are higher.Such oil-gas reservoir belongs to canonical biometric LIMESTONE RESERVOIR, and reservoir is thin and concentrates, fracture development compared with
It is good, depollution is solved by acidification, it is obvious to link up fracture stimulation effect：Average year increases the nearly 4000t of oil.
Acid stimulation measure is carried out to high water-cut well at present, is had the following problems：
(1) water ratio in oil well is further up after acidification measure.Implemented altogether by statistics Dagang Oilfield -2016 years 2014
Oil well acidation well effect analysis, wherein largely water outlet causes failure to account for 21.23% after acidification, and rise year by year (2014 12%,
2015 20%, 2016 27%).The reason is that high-water-cut oil-producing well carries out conventional acidulation transformation, acid solution prolongs macropore or height for analysis
Band fingering is seeped, preferentially enters high aquifer formation, moisture content is further up after acid.
(2) tool separate layer acid treatment is used, limitation is strong.First water detection layer is needed, then is insulated using long glue bucket packer, underseal
The technology mode that device etc. blocks water layer mono-acid oil reservoir is not able to satisfy water outlet and the acidification of grease alternating layers well transformation demand in layer.
(3) grout off water layer is acidified again, and pressure discharge capacity is limited.It needs first to find accurately water layer, then with grout off, penetrates out again
Oil reservoir, then acid stimulation, technique is cumbersome, and due to the acidproof resistance to pressure problem of cement, acidizing treatment discharge capacity, pressure are limited, influence
Acidizing effect.
Above various technologies, which exist, applies upper limitation, thus effect is undesirable in some cases.
Summary of the invention
In view of this, the present invention is directed to propose a kind of be used for high water-cut reservoir water-control oil-increasing acidification technique method, to overcome
The problems such as effect of the existing technology is poor, limitation is strong, technique was both safe and reliable, increased while controlling water ratio in oil well
Well oil output improves well stimulation effect, improves producing well development benefit.
In order to achieve the above objectives, the technical proposal of the invention is realized in this way：
One kind is for the agent of high water-cut reservoir water-control oil-increasing, the component including following mass fraction, 2%-3% potassium chloride,
0.1%-0.5% thickener, 1%-10% oil-soluble phenolic resin, 2%-3% pressure break cleanup additive, remaining is water, and each group
The sum of mass fraction divided is 100%.
Preferably, the thickener is polyacrylamide；The pressure break is fluorocarbon surfactant with cleanup additive.
The present invention also provides one kind to be used for high water-cut reservoir water-control oil-increasing acidification technique method, successively makes to reservoir to be processed
It is handled with treatment fluid, main body acid solution, treatment fluid, water-control oil-increasing agent, treatment fluid, main body acid solution, treatment fluid；The control water increases
Finish is to be used for the agent of high water-cut reservoir water-control oil-increasing as described above.
Preferably, the treatment fluid includes the component of following mass fraction, the industrial synthetic hydrochloric acid of 10%-15%, 3%-
10%, which recovers the oil, uses stratum cleaning agent, and 2%-5%, which recovers the oil, uses wetting agent, 1-5% acidification corrosion inhibiter, the 2%-3% pressure break row of helping
Ferrous stability is used in agent, 2%-3% acidification；2%-5% clay stabilizer, remaining is water, and the mass fraction of each component it
Be 100%.
Preferably, for carbonate reservoir, the main acid used includes the component of following mass fraction, 10%-15%
Industrial synthetic hydrochloric acid, 3%-10% industrial acetic, 2%-5%, which recovers the oil, uses wetting agent, 1~5% acidification corrosion inhibiter, 2%-
3% pressure break cleanup additive, 2%-3% acidification ferrous stability, 2%-5% clay stabilizer, remaining is water, and each component
The sum of mass fraction be 100%；
For sandstone or igneous reservoirs, the main acid used includes the component of following mass fraction, 10%-15% industry
With synthetic hydrochloric acid, 1%-3% industrial hydrofluoric acid, 2%-5%, which recovers the oil, uses wetting agent, 2% acidification corrosion inhibiter, 2%-3% pressure break
With cleanup additive, 2%-3% acidification ferrous stability, 2%-5% clay stabilizer, remaining is water, and the quality of each component
The sum of score is 100%.
Preferably, oil recovery is phenol ether, toluene, fatty alcohol polyoxyethylene ether, aliphatic alcohol polyethenoxy with stratum cleaning agent
Ether acid salt, one of alkyl phenol polyoxyethylene ether or a variety of；The oil recovery is alkyl trimethyl ammonium bromide, amber with wetting agent
Acid ester sulfonates, high fatty acid amide sulfonate, one of polyoxyethylene fatty acid ester or a variety of；Corrosion inhibiter is used in the acidification
For Mannich base, propilolic alcohol, fatty amine and its derivative, quaternary ammonium salt, amide carboxylic acid's type, rosin derivative species corrosion inhibiter, pyrrole
One of pyridine class corrosion inhibiter is a variety of；The pressure break is fluorocarbon surfactant, polyoxyethylene ether-ester salt both sexes with cleanup additive
One of surfactant, hydrocarbon cationic surfactant are a variety of；The acidification with ferrous stability be citric acid,
One of EDETATE DISODIUM, oxalic acid and glacial acetic acid are a variety of；The clay stabilizer is organic salt, quaternary, pyridiniujm
One of type, imidazoline salt form cationic surface active agent and its polymer, alkyl halogen silyl are a variety of.
Preferably, include the following steps,
1) treatment fluid is replaced from oil pipe into dosage is 1 times of flow line volume；
2) treatment fluid is injected from oil pipe, treatment fluid dosage is { target zone perforation thickness × (2~15) m3/ m's is strong with acid
Degree } × high permeability formation thickness/total perforation thickness；
3) main body acid solution is injected from oil pipe, main body acid solution dosage is { π × perforation thickness × average pore × processing half
Diameter2} × high permeability formation thickness/total perforation thickness；The treatment radius is 1m~3m；
4) treatment fluid is injected from oil pipe, treatment fluid dosage is 1/4~1/2 of main acid dosage in step 2)；
5) water-control oil-increasing agent is injected from oil pipe, needs the 0.3- of plugged zone thickness for the purpose of water-control oil-increasing agent dosage in layer
1.5m3/m；
6) treatment fluid is injected from oil pipe, dosage is { target zone perforation thickness × (2~15) m3The use acid strength of/m } ×
Low-permeability layer thickness/total perforation thickness；
7) main body acid solution is injected from oil pipe, dosage is { π × perforation thickness × average pore × treatment radius2} × low
Alloying layer thickness/total perforation thickness；The treatment radius is 1m~3m；
8) treatment fluid is injected from oil pipe, dosage is 1/4~1/2 of main acid dosage in step 7)；
9) squeezing aforesaid liquid finishes, and squeezes into displacement fluid from oil pipe, replaces liquid measure and is greater than 1.5 times of oil pipe volume；
10) squeezing displacement fluid finishes, and carries out residual acid immediately and returns row；Preferably, the displacement fluid is clear water or clay temperature
Determine the mixture of agent and clear water, the mass percent that the clay stabilizer accounts for displacement fluid is 1~3%, preferred 2%.
Each step pump pressure requires subject to all in accordance with the safe-working pressure value of production tree, oil pipe or other well control devices,
Under safe-working pressure, the unlimited discharge capacity injection of pressure limiting.If well head uses 250 model production tree, injection pressure≤21MPa, well head is adopted
With 350 type production trees, injection pressure≤34MPa.
Preferably, when reservoir is carbonate rock or igneous reservoirs, operating procedure 4 is not needed) and step 8).
Compared with the existing technology, of the present invention to have the advantage that：
(1) water-control oil-increasing agent of the present invention has the characteristics that " the molten water blocking of oil ", is able to achieve chemo-selective from primary seal
Water-blocking layer.
(2) technique of the present invention can release reservoir pollution, improve reservoir permeability emphatically, prevent or reduce acid solution and exist
Speed of advancing by leaps and bounds in water layer is linked up or is extended layer crack, widens crude oil flow channel.
(3) water-control oil-increasing agent of the present invention and technique have relatively strong suitable in High water cut block stimulation of well
The property used.
(4) water-control oil-increasing agent of the present invention and technique reduce moisture content while being able to achieve increasing oil；And technique uses
Single time tubing string realizes that oil-water common-layer, grease alternating layers water-control oil-increasing and acid stimulation, construction safety are simple and effective.
Detailed description of the invention
Fig. 1 is surface line flow chart；
Fig. 2 is underground construction tubing string figure；
1. handling flow container, 2. main acid A tanks, 3. water-control oil-increasing agent tanks, 4. main acid B tanks, 5. replace flow container, 6. first valves
Door, 7. second valves, 8. third valves, 9. the 4th valves, 10. the 5th valves, 11. pumps, 12. high pressure lines, 13. production trees,
14. oil pipe, 15. production strings, 16. target zones, 17. surface pipes, 18. protective casings.
Specific embodiment
In addition to being defined, technical term used in following embodiment has universal with those skilled in the art of the invention
The identical meanings of understanding.Test reagent used in following embodiment is unless otherwise specified conventional biochemical reagent；It is described
Experimental method is unless otherwise specified conventional method.
Below with reference to embodiment, the present invention will be described in detail.
Before being constructed, surface line and tank connection are first carried out, as shown in Figure 1, including the following steps：
1, treatment fluid, main acid, water-control oil-increasing agent and displacement fluid are put into respectively corresponding tank respectively, and connect height
Pressure pipeline；
2, construction tank is connected with high pressure line, sequentially turned-on valve connects production tree with high pressure line；
3, well head installs production tree.
The structure of underground construction tubing string, as shown in Fig. 2, oil pipe 14 is sleeved in production string 15, remaining structure is referring to attached
Fig. 2.
Embodiment 1
A1 well, target zone are sandstone, measure day before yesterday oil-producing 0.8t, moisture content 94.8%.Its condition of production is shown in Table 1
The condition of production before 1 A1 well measure of table
According to reservoir and crude oil property, using water-control oil-increasing acidification technique, Specific construction pump note program is：
1. seeping situation according to reservoir hole, calculate and use acid strength, treatment radius and water-control oil-increasing agent dosage, according to measure formula point
It Pei Zhi not treatment fluid 80m3, main body acid solution 60m3, water-control oil-increasing agent 15m3, displacement fluid 10m3；
2. connection injection pipeline, opens Christmas tree casing valve, starts injecting program；
3. low pump pressure injects treatment fluid 6m3, make it full of oil pipe, be then shut off sleeve valve；
4. huge discharge is implanted sequentially treatment fluid 19m under limitation pump pressure 21MPa3, main body acid solution 30m3, treatment fluid 15m3, just
Walk corrosion target zone.
5. being pumped 21MPa, water-control oil-increasing agent 15m is injected3, selectivity handles aqueous main contributions layer, reduce High water cut or
The permeability of the preferable layer position of water layer connectivity；
6. continuing huge discharge is implanted sequentially treatment fluid 25m3, main body acid solution 30m3, treatment fluid 15m3, to oil reservoir after closure into
Row acidification improves reservoir permeability.
7. injecting 10m3Displacement fluid, it is ensured that whole acid solutions enter reservoir and sufficiently react.
8. note displacement fluid terminates, acid filling pipeline is removed, according to the big minor adjustment difference oil nozzle open flow of oil pressure.
9. after open flow does not go out, flowing back by hydraulic pump is carried out, until raffinate pH value 6-7 is qualification.
10. completing oil well production string normally to be produced.
Day, oil-producing rose to 2.5t after the well measure, aqueous to drop to 79.2%, achieved good water-control oil-increasing effect.
Wherein water-control oil-increasing agent, the component including following mass fraction, 2% potassium chloride, 0.2% thickener, 3% oil-soluble
Phenolic resin, 2% pressure break cleanup additive, remaining is water, and the sum of mass fraction of each component is 100%.The thickener is
Polyacrylamide；The pressure break is fluorocarbon surfactant with cleanup additive.
The treatment fluid, the component including following mass fraction, 11% industrial synthetic hydrochloric acid, 4% oil recovery stratum are clear
Ferrous stability is used in lotion, 3% oil recovery wetting agent, 1% acidification corrosion inhibiter, 2% pressure break cleanup additive, 2% acidification；
2% clay stabilizer, remaining is water, and the sum of mass fraction of each component is 100%.
The main acid used includes the component of following mass fraction, 11% industrial synthetic hydrochloric acid, 2% industrial hydrofluoric acid,
3%, which recovers the oil, uses wetting agent, 2% acidification corrosion inhibiter, 2% pressure break cleanup additive, 2% acidification ferrous stability, 3% clay
Stabilizer, remaining is water, and the sum of mass fraction of each component is 100%.
Oil recovery is phenol ether with stratum cleaning agent；The oil recovery is alkyl trimethyl ammonium bromide with wetting agent；The acidification
It is compound pyridine quaternary ammonium salt with corrosion inhibiter；The pressure break is fluorocarbon surfactant with cleanup additive；The acidification iron ion is steady
Determining agent is EDTA divalent sodium salt；The clay stabilizer is polyquaternium cationic surfactant.
Embodiment 2
B well, the well target zone are that the well target zone is Es1, and exploitation oil reservoir is 4 layers, and lithology biogenic limestone belongs to carbonate
Rock reservoir.Its crude oil situation is shown in Table 2
The condition of production before 2 B well measure of table
According to reservoir and crude oil property, using water-control oil-increasing chemical industry skill, Specific construction pump note program is：
1. seeping situation according to reservoir hole, calculate and use acid strength and water-control oil-increasing agent dosage, is prepared respectively according to measure formula
Treatment fluid 65m3, main acid 40m3, water-control oil-increasing agent 15m3, displacement fluid 10m3；
2. connection injection pipeline, opens Christmas tree casing valve, starts injecting program；
3. injecting treatment fluid 4m in a manner of the low discharge capacity of low pump pressure3, make it full of oil pipe, be then shut off sleeve valve；
4. huge discharge injects treatment fluid 26m under limitation pump pressure 21MPa3, preliminary corrosion reservoir releases each layer near wellbore zone
Pollution；
5. huge discharge injects main acid 15m under limitation pump pressure 21MPa3；
6. being pumped 21MPa, water-control oil-increasing agent 15m is injected3, selectivity handles aqueous main contributions layer, reduce High water cut or
The permeability of the preferable layer position of water layer connectivity；
7. continuing huge discharge is implanted sequentially treatment fluid 35m3, main body acid solution 25m3, selectivity acid is carried out to oil reservoir after closure
Change, reaches the measure purpose for increasing oil control water；
8. injecting 10m3Displacement fluid, it is ensured that whole acid solutions enter reservoir and sufficiently react；
9. note displacement fluid terminates, acid filling pipeline is removed, according to the big minor adjustment difference oil nozzle open flow of oil pressure；
10. after open flow does not go out, flowing back by hydraulic pump is carried out, until raffinate pH value 6-7 is qualification；
Oil well production string is completed normally to be produced；
Day, oil-producing rose to 6.1t after the well measure, aqueous to drop to 80.2%, achieved good water-control oil-increasing effect.
Wherein, water-control oil-increasing agent, the component including following mass fraction, 3% potassium chloride, 0.3% thickener, 6% oil are molten
Property phenolic resin, 3% pressure break cleanup additive, remaining is water, and the sum of mass fraction of each component be 100%.The thickener
For polyacrylamide；The pressure break is fluorocarbon surfactant with cleanup additive.
The treatment fluid includes the component of following mass fraction, 15% industrial synthetic hydrochloric acid, and 10% oil recovery stratum is clear
Ferrous stability is used in lotion, 3% oil recovery wetting agent, 2% acidification corrosion inhibiter, 2% pressure break cleanup additive, 3% acidification；
2% clay stabilizer, remaining is water, and the sum of mass fraction of each component is 100%.
The main body acid solution used includes the component of following mass fraction, 13% industrial synthetic hydrochloric acid, 2% industrial hydrogen fluorine
Acid, 4% oil recovery wetting agent, 2% acidification corrosion inhibiter, 3% pressure break cleanup additive, 2% acidification ferrous stability, 4%
Clay stabilizer, remaining is water, and the sum of mass fraction of each component is 100%.
Oil recovery is phenol ether with stratum cleaning agent；The oil recovery is polyoxyethylene fatty acid ester with wetting agent；The acidification
It is Mannich base corrosion inhibiter with corrosion inhibiter；The pressure break is fluorocarbon surfactant with cleanup additive；The acidification iron ion is steady
Determining agent is EDTA divalent sodium salt；The clay stabilizer is polyquaternium cationic surfactant.
The foregoing is merely illustrative of the preferred embodiments of the present invention, is not intended to limit the invention, all in essence of the invention
Within mind and principle, any modification, equivalent replacement, improvement and so on be should all be included in the protection scope of the present invention.
Claims (8)
1. one kind is used for the agent of high water-cut reservoir water-control oil-increasing, it is characterised in that：Component including following mass fraction, 2%-3%
Potassium chloride, 0.1%-0.5% thickener, 1%-10% oil-soluble phenolic resin, 2%-3% pressure break cleanup additive, remaining is water,
And the sum of mass fraction of each component is 100%.
2. according to claim 1 be used for the agent of high water-cut reservoir water-control oil-increasing, it is characterised in that：The thickener is poly- third
Acrylamide；The pressure break is fluorocarbon surfactant with cleanup additive.
3. one kind is used for high water-cut reservoir water-control oil-increasing acidification technique method, it is characterised in that：Reservoir to be processed is successively used
Treatment fluid, main body acid solution, treatment fluid, water-control oil-increasing agent, treatment fluid, main body acid solution, treatment fluid are handled；The water-control oil-increasing
Agent is of any of claims 1 or 2 for the agent of high water-cut reservoir water-control oil-increasing.
4. according to claim 3 be used for high water-cut reservoir water-control oil-increasing acidification technique method, it is characterised in that：The place
Reason liquid includes the component of following mass fraction, and the industrial synthetic hydrochloric acid of 10%-15%, 3%-10%, which recovers the oil, uses stratum cleaning agent,
2%-5%, which recovers the oil, uses wetting agent, 1-5% acidification corrosion inhibiter, 2%-3% pressure break cleanup additive, and iron ion is used in 2%-3% acidification
Stabilizer；2%-5% clay stabilizer, remaining is water, and the sum of mass fraction of each component is 100%.
5. according to claim 4 be used for high water-cut reservoir water-control oil-increasing acidification technique method, it is characterised in that：For carbon
Carbonate Reservoir, the main acid used include the component of following mass fraction, the industrial synthetic hydrochloric acid of 10%-15%, 3%-
10% industrial acetic, 2%-5%, which recovers the oil, uses wetting agent, 1~5% acidification corrosion inhibiter, 2%-3% pressure break cleanup additive,
2%-3% acidification ferrous stability, 2%-5% clay stabilizer, remaining is water, and the sum of the mass fraction of each component is
100%；
For sandstone or igneous reservoirs, the main body acid solution used includes the component of following mass fraction, and 10%-15% is industrial
Synthetic hydrochloric acid, 1%-3% industrial hydrofluoric acid, 2%-5%, which recovers the oil, uses wetting agent, 1~5% acidification corrosion inhibiter, 2%-3% pressure break
With cleanup additive, 2%-3% acidification ferrous stability, 2%-5% clay stabilizer, remaining is water, and the quality of each component
The sum of score is 100%.
6. according to claim 4 or 5 be used for high water-cut reservoir water-control oil-increasing acidification technique method, it is characterised in that：It adopts
Oil is phenol ether, toluene, fatty alcohol polyoxyethylene ether, fatty alcohol polyoxyethylene ether hydrochlorate, alkyl phenol polyoxy with stratum cleaning agent
One of vinethene is a variety of；The oil recovery is alkyl trimethyl ammonium bromide, sulphosuccinates, advanced rouge with wetting agent
Fat amidosulfonic acid salt, one of polyoxyethylene fatty acid ester or a variety of；The acidification is Mannich base, propine with corrosion inhibiter
Alcohol, fatty amine and its derivative, quaternary ammonium salt, amide carboxylic acid's type, rosin derivative species corrosion inhibiter, one in pyridines corrosion inhibiter
Kind is a variety of；The pressure break is fluorocarbon surfactant, polyoxyethylene ether-ester salt amphoteric surfactant, hydrocarbon sun with cleanup additive
One of ionic surface active agent is a variety of；The acidification with ferrous stability be citric acid, EDETATE DISODIUM, oxalic acid and
One of glacial acetic acid is a variety of；The clay stabilizer be organic salt, quaternary, pyridine salt type, imidazoline salt form sun from
One of subtype surfactant and its polymer, alkyl halogen silyl are a variety of.
7. being used for high water-cut reservoir water-control oil-increasing acidification technique method according to claim 3~6 is described in any item, feature exists
In：Include the following steps,
1) treatment fluid is replaced from oil pipe into dosage is 0.9-1 times of flow line volume；
2) treatment fluid is injected from oil pipe, treatment fluid dosage is { target zone perforation thickness × (2~15) m3The use acid strength of/m } ×
High permeability formation thickness/total perforation thickness；
3) main body acid solution is injected from oil pipe, main body acid solution dosage is { π × perforation thickness × average pore × treatment radius2}
× high permeability formation thickness/total perforation thickness；Treatment radius is 1m~3m；
4) treatment fluid is injected from oil pipe, treatment fluid dosage is 1/4~1/2 of main acid dosage in step 2)；
5) water-control oil-increasing agent is injected from oil pipe, needs the 0.3-1.5 of plugged zone thickness for the purpose of water-control oil-increasing agent dosage in layer
Times m3/m；
6) treatment fluid is injected from oil pipe, dosage is { target zone perforation thickness × (2~15) m3The use acid strength of/m } × low-permeability layer
Thickness/total perforation thickness；
7) main body acid solution is injected from oil pipe, dosage is { π × perforation thickness × average pore × treatment radius2} × low-permeability layer
Thickness/total perforation thickness；Treatment radius is 1m~3m；
8) treatment fluid is injected from oil pipe, dosage is 1/4~1/2 of main acid dosage in step 7)；
9) aforesaid liquid squeezing finishes, and squeezes into displacement fluid from oil pipe, replaces liquid measure and is greater than 1.5 times of oil pipe volume；
10) squeezing displacement fluid finishes, and carries out residual acid immediately and returns row；Preferably, the displacement fluid is that clear water or clay temperature determine agent
With the mixture of clear water, the mass percent that the clay stabilizer accounts for displacement fluid is 1~3%, preferred 2%.
8. being used for high water-cut reservoir water-control oil-increasing acidification technique method according to claim 3~6 is described in any item, feature exists
In：When reservoir is carbonate rock or igneous reservoirs, operating procedure 4 is not needed) and step 8).
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810620657.6A CN108913118B (en) | 2018-06-15 | 2018-06-15 | Water-control oil-increasing acidification process method for high-water-content oil reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810620657.6A CN108913118B (en) | 2018-06-15 | 2018-06-15 | Water-control oil-increasing acidification process method for high-water-content oil reservoir |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN108913118A true CN108913118A (en) | 2018-11-30 |
| CN108913118B CN108913118B (en) | 2021-07-13 |
Family
ID=64420547
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201810620657.6A Active CN108913118B (en) | 2018-06-15 | 2018-06-15 | Water-control oil-increasing acidification process method for high-water-content oil reservoir |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN108913118B (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109967467A (en) * | 2019-03-04 | 2019-07-05 | 扬州中天利新材料股份有限公司 | The Hand scarf method of tank body oil-soluble deposition oil |
| CN110056334A (en) * | 2019-04-19 | 2019-07-26 | 中国石油天然气股份有限公司 | Oil well non-flowback working fluid and steering and energizing integrated totally-enclosed acidizing construction process |
| CN111621276A (en) * | 2019-02-27 | 2020-09-04 | 中国石油天然气股份有限公司 | Solid acid plugging agent and method for removing stratum plugging by using same |
| CN112377149A (en) * | 2020-12-09 | 2021-02-19 | 中国石油天然气集团有限公司 | Method for determining acid strength for washing horizontal water injection well |
| CN114059984A (en) * | 2020-08-03 | 2022-02-18 | 中国石油化工股份有限公司 | Chemical cold-production method for medium-low permeability strong water-sensitive heavy oil reservoir |
Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5979557A (en) * | 1996-10-09 | 1999-11-09 | Schlumberger Technology Corporation | Methods for limiting the inflow of formation water and for stimulating subterranean formations |
| CN1621485A (en) * | 2003-11-28 | 2005-06-01 | 大港油田集团有限责任公司 | Lower damage acidification system for high temperature carbonate reservoir |
| CN102732240A (en) * | 2011-04-11 | 2012-10-17 | 中国石油化工股份有限公司 | Self-distribution seepage-regulation water-controlling acidifying technology |
| CN104181594A (en) * | 2014-08-20 | 2014-12-03 | 辛治国 | Method for determining complex sedimentary body boundary |
| CN104419390A (en) * | 2013-09-04 | 2015-03-18 | 中国石油天然气股份有限公司 | Composite plugging agent for oil well water control and preparation method thereof |
| CN105401929A (en) * | 2014-09-09 | 2016-03-16 | 中国石油化工股份有限公司 | Even acid distribution method for acidification of heterogeneous storage layer |
| CN106382113A (en) * | 2016-09-07 | 2017-02-08 | 中国石油化工股份有限公司 | Temporary plugging steering acidification method applicable to sandstone reservoir |
| CN106967402A (en) * | 2017-03-16 | 2017-07-21 | 中国石油化工股份有限公司 | A kind of acidification blocking remover and its construction method suitable for deep volcanic rock gas reservoir |
| WO2018004624A1 (en) * | 2016-06-30 | 2018-01-04 | Halliburton Energy Services, Inc. | Acid diversion in naturally fractured formations |
-
2018
- 2018-06-15 CN CN201810620657.6A patent/CN108913118B/en active Active
Patent Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5979557A (en) * | 1996-10-09 | 1999-11-09 | Schlumberger Technology Corporation | Methods for limiting the inflow of formation water and for stimulating subterranean formations |
| CN1621485A (en) * | 2003-11-28 | 2005-06-01 | 大港油田集团有限责任公司 | Lower damage acidification system for high temperature carbonate reservoir |
| CN102732240A (en) * | 2011-04-11 | 2012-10-17 | 中国石油化工股份有限公司 | Self-distribution seepage-regulation water-controlling acidifying technology |
| CN104419390A (en) * | 2013-09-04 | 2015-03-18 | 中国石油天然气股份有限公司 | Composite plugging agent for oil well water control and preparation method thereof |
| CN104181594A (en) * | 2014-08-20 | 2014-12-03 | 辛治国 | Method for determining complex sedimentary body boundary |
| CN105401929A (en) * | 2014-09-09 | 2016-03-16 | 中国石油化工股份有限公司 | Even acid distribution method for acidification of heterogeneous storage layer |
| WO2018004624A1 (en) * | 2016-06-30 | 2018-01-04 | Halliburton Energy Services, Inc. | Acid diversion in naturally fractured formations |
| CN106382113A (en) * | 2016-09-07 | 2017-02-08 | 中国石油化工股份有限公司 | Temporary plugging steering acidification method applicable to sandstone reservoir |
| CN106967402A (en) * | 2017-03-16 | 2017-07-21 | 中国石油化工股份有限公司 | A kind of acidification blocking remover and its construction method suitable for deep volcanic rock gas reservoir |
Non-Patent Citations (6)
| Title |
|---|
| 《油矿修井工人读本》编写小组: "《油矿修井工人读本 下》", 31 July 1975, 石油化学工业出版社 * |
| 廖前时: "《钻采工程技术论文集》", 30 September 2009, 中国石油大学出版社 * |
| 杜丙国: "《井下作业技术规范》", 30 September 2007, 中国石油大学出版社 * |
| 樊勇杰: "靖吴油区中高含水区块控水增油技术研究与应用", 《长江大学学报(自科版)》 * |
| 王增林: "《国内外石油技术进展 2004》", 31 August 2005, 中国石化出版社 * |
| 葛红江: "裂缝性灰岩油藏堵水酸化联作技术研究与试验", 《断块油气田》 * |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111621276A (en) * | 2019-02-27 | 2020-09-04 | 中国石油天然气股份有限公司 | Solid acid plugging agent and method for removing stratum plugging by using same |
| CN109967467A (en) * | 2019-03-04 | 2019-07-05 | 扬州中天利新材料股份有限公司 | The Hand scarf method of tank body oil-soluble deposition oil |
| CN110056334A (en) * | 2019-04-19 | 2019-07-26 | 中国石油天然气股份有限公司 | Oil well non-flowback working fluid and steering and energizing integrated totally-enclosed acidizing construction process |
| CN114059984A (en) * | 2020-08-03 | 2022-02-18 | 中国石油化工股份有限公司 | Chemical cold-production method for medium-low permeability strong water-sensitive heavy oil reservoir |
| CN112377149A (en) * | 2020-12-09 | 2021-02-19 | 中国石油天然气集团有限公司 | Method for determining acid strength for washing horizontal water injection well |
Also Published As
| Publication number | Publication date |
|---|---|
| CN108913118B (en) | 2021-07-13 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN108913118A (en) | One kind being used for high water-cut reservoir water-control oil-increasing acidification technique method | |
| CN101353958B (en) | Oil-gas well exploitation temperature control variable mucic acid fracturing method | |
| CN102828734B (en) | Offshore oilfield water injection well online one-step-process acidification technology | |
| CN106246150B (en) | Oil field fracturing transformation method | |
| CN101555404B (en) | Environment-friendly low-damage solidfree well control fluid and applications thereof | |
| CN106194122B (en) | A kind of method that oil field abandoned well transform geothermal well or sub-salt well as | |
| CN105089600B (en) | Method for assisting horizontal well in dragging type hydraulic jet reconstruction through temporary blocking steering material | |
| He et al. | Development and prospect of separated zone oil production technology | |
| CN107216866A (en) | A kind of method that Carbonate Reservoir seam dictyosome accumulates acidfracturing treatment | |
| CN108343417A (en) | Method for temporary plugging layered reconstruction of gas well and application | |
| CN105089602A (en) | Variant-hydrochloric-acid-concentration acid fracturing method for carbonate reservoir | |
| CN112253071A (en) | Design method for pretreatment, blockage removal and capacity increase fracturing of compact sandstone reservoir | |
| CN109321220A (en) | Plugging agent for adjusting water absorption profile of immobile pipe column of water injection well and water absorption profile adjusting process | |
| CN102767353A (en) | Comprehensive mining technology of drowned well | |
| CN107246257B (en) | Heterogeneous reservoir is acidified remodeling method | |
| CN107882544B (en) | A kind of mixing heat release method for removing blockage for carbonate cementation molding sand rock heavy oil wells | |
| CN202659194U (en) | Novel well wall restoring device with combined sleeve and corrugated pipe | |
| CN109653723B (en) | Method for increasing volume fracturing effect of complex oil and gas layer fracture network | |
| CN105569602A (en) | Method for sealing channeling outside oil well pipe | |
| CN204283373U (en) | A kind of hydraulic jet perforation choke manifold | |
| CN104179488B (en) | A kind of method for improving exploitation hyposmosis carbonate rock heavy crude reservoir effect | |
| CN113969775B (en) | Method for improving effective acid etching seam length of ultra-deep carbonate reservoir and application | |
| Moffitt et al. | Application of freshwater and brine polymer flooding in the North Burbank Unit, Osage County, Oklahoma | |
| CN109294544A (en) | Non-oxidized polymer chemistry de-plugging gel breaker and preparation method thereof | |
| CN104449622B (en) | High temperature resistance high pressure organic composite type Oil layer protective solution and preparation method thereof |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| TA01 | Transfer of patent application right |
Effective date of registration: 20201104 Address after: No.3 Institute of Dagang Oilfield in Tianjin Binhai New Area Applicant after: DAGANG OILFIELD GROUP Co.,Ltd. Applicant after: CHINA NATIONAL PETROLEUM Corp. Address before: 300280 Dagang three, Binhai New Area, Tianjin Applicant before: DAGANG OILFIELD GROUP Co.,Ltd. |
|
| TA01 | Transfer of patent application right | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |