CN110273671A - A method of for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs - Google Patents
A method of for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs Download PDFInfo
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- CN110273671A CN110273671A CN201910304282.7A CN201910304282A CN110273671A CN 110273671 A CN110273671 A CN 110273671A CN 201910304282 A CN201910304282 A CN 201910304282A CN 110273671 A CN110273671 A CN 110273671A
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- Prior art keywords
- injection
- pressure
- organic
- slightly sour
- augmented injection
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- 239000007924 injection Substances 0.000 title claims abstract description 77
- 238000002347 injection Methods 0.000 title claims abstract description 77
- 238000000034 method Methods 0.000 title claims abstract description 37
- 230000003190 augmentative effect Effects 0.000 title claims abstract description 35
- 150000001875 compounds Chemical class 0.000 title claims abstract description 19
- 230000035699 permeability Effects 0.000 title claims abstract description 18
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 37
- 239000012530 fluid Substances 0.000 claims abstract description 26
- 239000002253 acid Substances 0.000 claims abstract description 22
- 239000007788 liquid Substances 0.000 claims abstract description 21
- 230000006378 damage Effects 0.000 claims abstract description 15
- 238000004140 cleaning Methods 0.000 claims abstract description 14
- 208000027418 Wounds and injury Diseases 0.000 claims abstract description 13
- 208000014674 injury Diseases 0.000 claims abstract description 13
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 9
- 230000008569 process Effects 0.000 claims abstract description 9
- 230000002378 acidificating effect Effects 0.000 claims abstract description 8
- 230000000694 effects Effects 0.000 claims abstract description 7
- 238000005530 etching Methods 0.000 claims abstract description 7
- 238000004090 dissolution Methods 0.000 claims abstract description 5
- 239000005416 organic matter Substances 0.000 claims abstract description 5
- 239000002131 composite material Substances 0.000 claims abstract description 4
- 230000008021 deposition Effects 0.000 claims abstract description 3
- 239000003795 chemical substances by application Substances 0.000 claims description 26
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims description 17
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 16
- 230000007797 corrosion Effects 0.000 claims description 13
- 238000005260 corrosion Methods 0.000 claims description 13
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 12
- 239000000654 additive Substances 0.000 claims description 11
- 238000005406 washing Methods 0.000 claims description 11
- 239000013505 freshwater Substances 0.000 claims description 10
- 229910052742 iron Inorganic materials 0.000 claims description 9
- KBPLFHHGFOOTCA-UHFFFAOYSA-N 1-Octanol Chemical compound CCCCCCCCO KBPLFHHGFOOTCA-UHFFFAOYSA-N 0.000 claims description 8
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 8
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 claims description 8
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 8
- 230000000996 additive effect Effects 0.000 claims description 8
- 238000011156 evaluation Methods 0.000 claims description 7
- 239000002904 solvent Substances 0.000 claims description 7
- 239000003292 glue Substances 0.000 claims description 6
- 238000002474 experimental method Methods 0.000 claims description 5
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims description 4
- 229910019142 PO4 Inorganic materials 0.000 claims description 4
- 238000004458 analytical method Methods 0.000 claims description 4
- 230000015556 catabolic process Effects 0.000 claims description 4
- LRMHFDNWKCSEQU-UHFFFAOYSA-N ethoxyethane;phenol Chemical compound CCOCC.OC1=CC=CC=C1 LRMHFDNWKCSEQU-UHFFFAOYSA-N 0.000 claims description 4
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 claims description 4
- 239000010452 phosphate Substances 0.000 claims description 4
- 229920002503 polyoxyethylene-polyoxypropylene Polymers 0.000 claims description 4
- 239000011734 sodium Substances 0.000 claims description 4
- 229910052708 sodium Inorganic materials 0.000 claims description 4
- 125000003258 trimethylene group Chemical group [H]C([H])([*:2])C([H])([H])C([H])([H])[*:1] 0.000 claims description 4
- 238000013461 design Methods 0.000 claims description 3
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 3
- 238000004364 calculation method Methods 0.000 claims description 2
- 238000012797 qualification Methods 0.000 claims description 2
- 239000013535 sea water Substances 0.000 claims description 2
- 125000005233 alkylalcohol group Chemical group 0.000 claims 1
- 230000005764 inhibitory process Effects 0.000 claims 1
- 238000005086 pumping Methods 0.000 claims 1
- 238000005516 engineering process Methods 0.000 abstract description 7
- 239000003960 organic solvent Substances 0.000 abstract description 4
- 230000000638 stimulation Effects 0.000 abstract description 4
- 238000011161 development Methods 0.000 abstract description 2
- 239000002332 oil field water Substances 0.000 abstract description 2
- 230000009466 transformation Effects 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 8
- 239000000243 solution Substances 0.000 description 7
- 208000010392 Bone Fractures Diseases 0.000 description 6
- 206010017076 Fracture Diseases 0.000 description 6
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 description 6
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 5
- 238000011049 filling Methods 0.000 description 5
- 238000007792 addition Methods 0.000 description 4
- 230000000903 blocking effect Effects 0.000 description 4
- 238000006073 displacement reaction Methods 0.000 description 4
- 239000011435 rock Substances 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- 239000001273 butane Substances 0.000 description 3
- 239000013043 chemical agent Substances 0.000 description 3
- 239000011159 matrix material Substances 0.000 description 3
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- POAOYUHQDCAZBD-UHFFFAOYSA-N 2-butoxyethanol Chemical group CCCCOCCO POAOYUHQDCAZBD-UHFFFAOYSA-N 0.000 description 2
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- 238000010586 diagram Methods 0.000 description 2
- 210000002615 epidermis Anatomy 0.000 description 2
- -1 iron ion Chemical class 0.000 description 2
- 239000006210 lotion Substances 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 238000005457 optimization Methods 0.000 description 2
- 230000020477 pH reduction Effects 0.000 description 2
- 229940051841 polyoxyethylene ether Drugs 0.000 description 2
- 229920000056 polyoxyethylene ether Polymers 0.000 description 2
- 210000003491 skin Anatomy 0.000 description 2
- 238000004457 water analysis Methods 0.000 description 2
- 239000012224 working solution Substances 0.000 description 2
- XFRVVPUIAFSTFO-UHFFFAOYSA-N 1-Tridecanol Chemical compound CCCCCCCCCCCCCO XFRVVPUIAFSTFO-UHFFFAOYSA-N 0.000 description 1
- DURPTKYDGMDSBL-UHFFFAOYSA-N 1-butoxybutane Chemical compound CCCCOCCCC DURPTKYDGMDSBL-UHFFFAOYSA-N 0.000 description 1
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 description 1
- LSNNMFCWUKXFEE-UHFFFAOYSA-M Bisulfite Chemical compound OS([O-])=O LSNNMFCWUKXFEE-UHFFFAOYSA-M 0.000 description 1
- 102000000429 Factor XII Human genes 0.000 description 1
- 108010080865 Factor XII Proteins 0.000 description 1
- PXGOKWXKJXAPGV-UHFFFAOYSA-N Fluorine Chemical compound FF PXGOKWXKJXAPGV-UHFFFAOYSA-N 0.000 description 1
- 241001074085 Scophthalmus aquosus Species 0.000 description 1
- 208000013201 Stress fracture Diseases 0.000 description 1
- 238000002679 ablation Methods 0.000 description 1
- KGBXLFKZBHKPEV-UHFFFAOYSA-N boric acid Chemical compound OB(O)O KGBXLFKZBHKPEV-UHFFFAOYSA-N 0.000 description 1
- 239000004327 boric acid Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000011109 contamination Methods 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- DDXLVDQZPFLQMZ-UHFFFAOYSA-M dodecyl(trimethyl)azanium;chloride Chemical group [Cl-].CCCCCCCCCCCC[N+](C)(C)C DDXLVDQZPFLQMZ-UHFFFAOYSA-M 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000000556 factor analysis Methods 0.000 description 1
- 239000000706 filtrate Substances 0.000 description 1
- 229910052731 fluorine Inorganic materials 0.000 description 1
- 239000011737 fluorine Substances 0.000 description 1
- MTNDZQHUAFNZQY-UHFFFAOYSA-N imidazoline Chemical compound C1CN=CN1 MTNDZQHUAFNZQY-UHFFFAOYSA-N 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 229910000015 iron(II) carbonate Inorganic materials 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 150000007522 mineralic acids Chemical class 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000011017 operating method Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 238000005325 percolation Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 238000009418 renovation Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000012216 screening Methods 0.000 description 1
- 239000013049 sediment Substances 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- HFQQZARZPUDIFP-UHFFFAOYSA-M sodium;2-dodecylbenzenesulfonate Chemical group [Na+].CCCCCCCCCCCCC1=CC=CC=C1S([O-])(=O)=O HFQQZARZPUDIFP-UHFFFAOYSA-M 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- DHCDFWKWKRSZHF-UHFFFAOYSA-L thiosulfate(2-) Chemical group [O-]S([S-])(=O)=O DHCDFWKWKRSZHF-UHFFFAOYSA-L 0.000 description 1
- FZGRPBJBMUNMQH-UHFFFAOYSA-N trimethyl-$l^{3}-chlorane Chemical group CCl(C)C FZGRPBJBMUNMQH-UHFFFAOYSA-N 0.000 description 1
- 235000020681 well water Nutrition 0.000 description 1
- 239000002349 well water Substances 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
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
-
- 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
-
- 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- 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
- E21B43/26—Methods for stimulating production by forming crevices or fractures
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (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)
- Inorganic Chemistry (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Cleaning By Liquid Or Steam (AREA)
Abstract
The invention discloses a kind of methods for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, include the following steps: S1, filter out the target well for being appropriate for slightly sour pressure composite blockage relieving augmented injection；S2, into target well, injection liquid medium makes near wellbore formation rupture to form microcrack and keep opening；S3, injection acid fluid system are as prepad fluid or the inorganic scale of after pad dissolution removal near wellbore zone；S4, injection acidic treatment liquid perform etching the crack wall surface of opening；S5, augmented injection effect is evaluated using injectivity index or daily water-injection rate.Further include the operation for removing organic plugging before carrying out step S3 if there are organic pluggings in target well: injecting organic cleaning fluid into target well to dissolve removal shaft bottom organic deposition and the injury of nearly well organic matter.Method of the invention integrates the technologies such as micro- fracturing fracture, organic solvent cleaning, acid-etched fracture transformation, realizes that offshore oilfield water injection well stimulation meets the requirement of the oil field development the injecting process " injecting enough water ".
Description
Technical field
The present invention relates to technical field of petroleum extraction, and in particular to it is multiple that one kind is suitable for the slightly sour pressure of marine High porosity high permeability reservoirs
The method for closing unblocking and injection increasing.
Background technique
Offshore oilfield the injecting process will lead to reservoir for various reasons and come to harm, can be using acidification breaking block treatment
It releases injury to a certain degree and restores water injection capacity.Currently, conventional acidulation technology (not forming microcrack), organic solvent cleaning solution
Except organic matter injury technology, extensive ACID FRACTURING TECHNOLOGY are widely used in sea, land sandstone oil reservoir oil reservoir.But it is effective to be acidified de-plugging
Phase reduces with the increase of reacidizing number, and more frequent de-plugging operation is needed just to be able to satisfy oil field development in turn
The requirement of " injecting enough water " is acidified costly.
Summary of the invention
The purpose of the present invention is for conventional Acidizing Technology reacidizing validity period is short, augmented injection effect is limited, acidification takes
With high severe situation, a kind of method for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs is provided.This method is suitable for
The marine high hypertonic sandstone oil reservoir water injection well in hole, if such well is easy to cause reservoir matrix to collapse using conventional ACID FRACTURING TECHNOLOGY
The problems such as sand.
The method that the present invention is suitable for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, comprises the following steps step:
S1, core experiment evaluation or theoretical analysis method based on brill Completion Operations, the injecting process, all previous operation process
It evaluates and screens out and is appropriate for slightly sour pressure composite blockage relieving augmented injection well.Specifically, dynamic change is filled the water based on water injection well, using chemical examination
The clear water injection capacity decrease reason of the methods of water analysis ingredient, damage evaluation test, theory analysis is mainly that shaft bottom and nearly well have
Machine injury, the other injuries of nearly well.It is decomposed according to skin factor and water analysis finally determines.
S2, into target well, injection liquid medium makes near wellbore formation rupture to form microcrack and keep opening, and is subsequent note
Enter the entrance of organic cleaning fluid section to create conditions.Concrete operations are as follows: platform injection water is added in injection water in advance；According to casing programme,
The qualifications such as well head and equipment, formation fracture pressure determine the highest voltage limiting value of injection pressure；According to maximum injection discharge capacity
1/4 or 0.1m3For/min as initial injection discharge capacity, ladder proposes discharge capacity, and discharge capacity is incremented by with step until operation pressure reaches most
High voltage limiting value, and metering pressure and displacement variation relationship, make pressure-discharge capacity relational graph, and corresponding to displacement constant, pressure is bright
The point of aobvious decline is breakdown point.
S3, injection acid fluid system are as prepad fluid or the inorganic scale of after pad dissolution removal near wellbore zone.
S4, injection acidic treatment liquid perform etching the crack wall surface of opening.
S5, augmented injection effect is evaluated using injectivity index or daily water-injection rate.According to the test pressure spot test before fracturing methods
Corresponding stable water injection rate, and thus calculate injectivity index.Injectivity index after comparison measure and before measure, with augmented injection than evaluating
Water injection well stimulation effect.
It further include that removal is organic stifled before carrying out step S3 if there are organic pluggings in target well in the above method
The operation of plug: organic cleaning fluid is injected into target well to dissolve removal shaft bottom organic deposition and the injury of nearly well organic matter.It is organic clear
Washing lotion also helps step S3 after removing organic matter, and reservoir inorganic dirt is allowed sufficiently to contact with inorganic acid acid fluid system.It is described to have
Machine cleaning solution is formed by water-soluble organic washing agent and water according to volume ratio 1:5 mixed configuration.The organic washing agent is by as follows
The group of mass percent is grouped as: polyoxethylene octylphenyl phenol ether trimethylene sodium sulfonate 73%, polyoxyethylene polyoxypropylene butane group
Alcohol ether phosphate 17%, n-octyl alcohol 5%, isopropanol 5%.The calculation formula for injecting the volume Q of organic cleaning fluid is as follows:
Q=π (R-r)2* h,
Wherein, R is design reservoir treatment radius, unit m；R is pit shaft internal diameter, unit m；H is the effective vertical thickness of reservoir,
Unit m.
Preferably, the liquid medium is the mixed liquor at one or both of platform water source, seawater, fresh water.
Preferably, the acid fluid system in the step S3 is the liquid of weak corrosion, by the group of following percent by volume
Be grouped as: the steady agent 1% of hydrochloric acid 12%, acetic acid 5%, micellar 5%, corrosion inhibiter 1%, iron, glue steady agent 1%, cleanup additive 1%, mutually
Solvent 5%, remaining is fresh water.Acid fluid system preparation method: hydrochloric acid, acetic acid, corrosion inhibiter, other additions are sequentially added into fresh water
Agent.The existing successive requirement of the addition sequence of other additives.Acid fluid system, which has, to be released inorganic blocking ability and dissolves calcareous, guarantor
Low pH function is held, isolation crude oil is contacted with acid solution.
Preferably, acidic treatment liquid is grouped as by the group of following percent by volume in the step S4: hydrochloric acid 10%, fluorine
The steady agent 1% of boric acid 8%, hydrofluoric acid 2%, corrosion inhibiter 1%, iron, glue steady agent 2%, cleanup additive 1%, remaining be fresh water.Acidic treatment
Liquid configuration method: hydrochloric acid, fluoboric acid, hydrofluoric acid, corrosion inhibiter, other additives are sequentially added into fresh water.Other additives
The existing successive requirement of addition sequence.The acidic treatment liquid gos deep into the further etching fracture in crack, reaches fast reaction using strong acid
Purpose；There is preferable slow speed effect simultaneously, earth formation deep injury can be released, increase treatment radius.
Compared with prior art, the invention has the following advantages:
The micro- fracturing fracture technology of integrated application of the present invention, organic solvent cleaning, acid-etched fracture renovation technique are in one.With flat
The progress minute-pressure of platform source water, which is split, (injects the liquid medium for not adding proppant i.e. stopping after near wellbore reservoir forms microcrack
The short time fracturing technique of pressure break), nearly well band organic plugging is cleaned using organic solvent and releases Partial Blocking, injection acid solution is molten
Soluble matrix in crack is solved, increases nearly well band fracture condudtiviy and is opened to realize that offshore oilfield water injection well stimulation is able to satisfy the oil field
Send out the requirement of the injecting process " injecting enough water ".On the one hand it is utilized the opening of nearly well rock stratum and/or shearing slip acts on being formed has
The artificial short crack of certain flow conductivity, while effectively being dissolved using the nearly well organic plugging object of organic cleaning fluid slug,
Porosity and permeability is improved using acid solution dissolution stratum matrix soluble fraction, realizes and restores and improve water injection well water injection capacity
Augmented injection purpose.
Further advantage, target and feature of the invention will be partially reflected by the following instructions, and part will also be by this
The research and practice of invention and be understood by the person skilled in the art.
Detailed description of the invention
Fig. 1 be the de-plugging of example well before fill the water performance graph.
Fig. 2 is influence of the microcrack flow conductivity to augmented injection ratio.
Fig. 3 is that variation relation is compared in the augmented injection of water injection well past release epidermis.
Fig. 4 is the molten etching wall surface image of acid.
Fig. 5 is the injectivity index comparison diagram before and after measure.
Specific embodiment
Present invention will be described in further detail below with reference to the accompanying drawings, to enable those skilled in the art referring to specification text
Word can be implemented accordingly.
It should be appreciated that such as " having ", "comprising" and " comprising " term used herein do not allot one or more
The presence or addition of a other elements or combinations thereof.
The method of the compound augmented injection of slightly sour pressure of the invention is applied to the oil field Bo Nan BZ-X well, specific steps are as follows:
Step 1: the screening of measure water injection well
BZ-X is a bite orientation water injection well of the oil field the BZ wellblock Xi Kuai1D in Bohai Sea.Finishing drilling well depth 2394.00m, vertical depth
1788.34m, 49.76 ° of maximum hole deviation, vertical depth 1615.6m in the middle part of perforation, perforation hang down thickness 28.5m.The hollow integrated layered of tripping in is matched
Tubing string is infused, the first sand control section water nozzle is closed, and the second sand control section water nozzle is opened.It bets on September 30th, 2015, oil pressure 1.3MPa, day
Fill the water 72m3.There is pollution in the Site Test Analysis well skin factor 12 or so, shaft bottom.Main cause is caused during being drilled well
Injury (add up leakage 260 side of completion fluid during complete well, being drilled working solution filtrate intrusion during well may cause to hurt to reservoir
Evil), in the injecting process caused by injury (blocking caused by injection water section index exceeding standard, iron ion phase after mixed water injection of mainly removing contamination
The sediment and generation CaCO of pass3Fouling additionally includes and FeCO3And Fe2+Corresponding corrosion product causes reservoir to block),
(well is concentrated water filling, is on the one hand made after multiple high pressure excitement augmented injection operation, high pump pressure huge discharge for injury caused by previous measure
Near wellbore zone microcrack opens, and significantly improves stratum water absorbing capacity, and it is solid on the other hand to will also result in stratum under the conditions of strong erosion
Phase particle ablation forms fine migration blocking, while some tampers near wellbore zone may also be pushed into earth formation deep, make
It is blocked at earth formation deep).Wherein filling the water injury caused by stage and all previous measure may be more serious.Type of injury is with micro-
Based on grain migration and fouling etc., cause to result in blockage around near wellbore zone and screen casing.Therefore, it is asked to solve to improve water filling deficiency
Topic, using the compound augmented injection method of slightly sour pressure of the invention.
Step 2: working solution system selects
(1) configuration injects water and injection platform is added.
(2) according to the formula composition of chemical agent compatibility and rock core flowing experiment evaluation optimization organic cleaning fluid.It is organic clear
Washing lotion is formed by water-soluble organic washing agent and water according to volume ratio 1:5 mixed configuration.The organic washing agent is by following quality
The group of percentage is grouped as: polyoxethylene octylphenyl phenol ether trimethylene sodium sulfonate 73%, polyoxyethylene polyoxypropylene butane group alcohol ether
Phosphate 17%, n-octyl alcohol 5%, isopropanol 5%.
(3) matching for the front/rear weak corrosion acid fluid system set is optimized according to chemical agent compatibility and rock core flowing experiment evaluation
Fang Zucheng.Acid fluid system is grouped as by the group of following percent by volume: hydrochloric acid 12%, acetic acid 5%, micellar 5%, corrosion inhibiter
1%, the steady agent 1% of iron, glue steady agent 1%, cleanup additive 1%, mutual solvent 5%, remaining is fresh water.Wherein, micellar is isomery 13
Alcohol polyoxyethylene ether, corrosion inhibiter are thiosulfates imidazolines, and the steady agent of iron is citric acid, and gluing steady agent is trimethyl chlorine
Change ammonium, cleanup additive is neopelex, and mutual solvent is ethylene glycol monobutyl ether.
(4) according to the formula composition of chemical agent compatibility and rock core flowing experiment evaluation optimization acidic treatment liquid.At acidity
Reason liquid is grouped as by the group of following percent by volume: hydrochloric acid 10%, fluoboric acid 8%, hydrofluoric acid 2%, corrosion inhibiter 1%, the steady agent of iron
1%, glue steady agent 2%, cleanup additive 1%, remaining be fresh water.Wherein, micellar is isomerous tridecanol polyoxyethylene ether, and corrosion inhibiter is
Thiosulfates imidazoline, the steady agent of iron is citric acid, and gluing steady agent is dodecyl trimethyl ammonium chloride, and cleanup additive is dodecyl
Benzene sulfonic acid sodium salt, mutual solvent are ethylene glycol monobutyl ethers.
Injection liquid scale design is shown in Tables 1 and 2.
Table 1 matches liquid table
Table 2, organic washing slug
| Title | Cleaning solution | Displacement fluid | It amounts to |
| Liquid volume (m3) | 6 | 10 | 16 |
| Organic washing agent (kg) | 5200 | 0 | 5200 |
| Mutual solvent (kg) | 300 | 0 | 300 |
| GEOTHERMAL WATER (m3) | 0 | 10 | 10 |
Organic washing agent is made of the component of following mass percent in table 2: polyoxethylene octylphenyl phenol ether trimethylene sulfonic acid
Sodium 73%, polyoxyethylene polyoxypropylene butane group alcohol ether phosphate 17%, n-octyl alcohol 5%, isopropanol 5%.Mutual solvent is second two
Alcohol monobutyl ether.
Step 3: implementation steps, concrete operations details is as shown in table 3, including step 1-8.Obtained micro- fracture acidizing solution
Water filling performance graph when stifled construction is shown in Fig. 1.Fig. 1 corresponds to displacement constant and point that pressure is decreased obviously is breakdown point.B is micro-
Fig. 2 is shown in influence of the fracture condudtiviy to augmented injection ratio.The augmented injection of past release epidermis is shown in Fig. 3 than variation relation.The molten etching of acid is split
The image in slotted wall face is shown in Fig. 4.Injectivity index comparison diagram before and after BZ-X well measure is shown in Fig. 5.
Table 3, specific implementation operating procedure
In conclusion of the invention is suitable for the slightly sour compound augmented injection method of pressure of marine High porosity high permeability reservoirs mainly for water filling
Well acidizing validity period is short, the unconspicuous difficult point of augmented injection effect, using the slightly sour compound augmented injection process of pressure, is improved by a variety of mechanism close
Well percolation ability improves water injection well stimulation ratio.
Although the embodiments of the present invention have been disclosed as above, but its is not only in the description and the implementation listed
With.It can be applied to various suitable the field of the invention completely.It for those skilled in the art, can be easily
Realize other modification.Therefore without departing from the general concept defined in the claims and the equivalent scope, the present invention is simultaneously unlimited
In specific details and legend shown and described herein.
Claims (10)
1. a kind of method for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that including into target well
Injection liquid medium makes near wellbore formation rupture the step of forming microcrack, and the inorganic of near wellbore zone is removed in injection acid fluid system dissolution
The step of dirt, and the step of injection acidic treatment liquid performs etching the crack wall surface of opening.
2. the method as described in claim 1 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that packet
Include following steps:
S1, the target well for being appropriate for slightly sour pressure composite blockage relieving augmented injection is filtered out；
S2, into target well, injection liquid medium makes near wellbore formation rupture to form microcrack and keep opening；
S3, injection acid fluid system are as prepad fluid or the inorganic scale of after pad dissolution removal near wellbore zone；
S4, injection acidic treatment liquid perform etching the crack wall surface of opening；
S5, augmented injection effect is evaluated using injectivity index or daily water-injection rate.
3. the method as claimed in claim 2 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that institute
State the mixed liquor that liquid medium is one or both of platform water source, seawater, fresh water.
4. the method as claimed in claim 2 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that institute
The liquid that the acid fluid system in step S3 is weak corrosion is stated, is grouped as by the group of following percent by volume: hydrochloric acid 12%, acetic acid
5%, the steady agent 1% of micellar 5%, corrosion inhibiter 1%, iron, glue steady agent 1%, cleanup additive 1%, mutual solvent 5%, remaining is fresh water.
5. the method as claimed in claim 2 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that institute
It states treatment fluid in step S4 to be grouped as by the group of following percent by volume: hydrochloric acid 10%, fluoboric acid 8%, hydrofluoric acid 2%, inhibition
Agent 1%, the steady agent 1% of iron, glue steady agent 2%, cleanup additive 1%, remaining be fresh water.
6. the method for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs as described in claim 1-5 any one,
It is characterized in that, further includes the operation for removing organic plugging before carrying out step S3 if there are organic pluggings in target well: to
Organic cleaning fluid is injected in target well to dissolve removal shaft bottom organic deposition and the injury of nearly well organic matter.
7. the method as claimed in claim 6 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that note
The calculation formula for entering the volume Q of organic cleaning fluid is as follows:
Q=π (R-r)2* h,
Wherein, R is design reservoir treatment radius, unit m；R is pit shaft internal diameter, unit m；H is the effective vertical thickness of reservoir, unit
m。
8. the method as claimed in claim 7 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that institute
State organic cleaning fluid and formed by water-soluble organic washing agent and water according to volume ratio 1:5 mixed configuration, the organic washing agent by
The group of following mass percent is grouped as: polyoxethylene octylphenyl phenol ether trimethylene sodium sulfonate 73%, polyoxyethylene polyoxypropylene fourth
Alkyl alcohol ether phosphate 17%, n-octyl alcohol 5%, isopropanol 5%.
9. the method as claimed in claim 2 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that step
In rapid S1, based on the core experiment evaluation or theoretical analysis method evaluation for boring Completion Operations, the injecting process, all previous operation process
It filters out and is appropriate for slightly sour pressure composite blockage relieving augmented injection well.
10. the method as claimed in claim 2 for the slightly sour compound augmented injection of pressure of marine High porosity high permeability reservoirs, which is characterized in that
In step S2, the highest pressure limiting of injection pressure is determined according to casing programme, well head and equipment, formation fracture pressure qualifications
Value；Initial injection discharge capacity is 0.1m3/ min, ladder propose discharge capacity, and discharge capacity is incremented by with step until operation pressure reaches highest and limits
Pressure value；And differentiate minute-pressure splits whether breakdown point occur based on operation pressure curve, if there is breakdown point termination of pumping immediately.
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