CN110173251A - Compact oil reservoir CO2Auxiliary energy-storage imbibition fracturing process - Google Patents
Compact oil reservoir CO2Auxiliary energy-storage imbibition fracturing process Download PDFInfo
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- CN110173251A CN110173251A CN201910563020.2A CN201910563020A CN110173251A CN 110173251 A CN110173251 A CN 110173251A CN 201910563020 A CN201910563020 A CN 201910563020A CN 110173251 A CN110173251 A CN 110173251A
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- imbibition
- proppant
- slippery water
- frozen glue
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- 238000005213 imbibition Methods 0.000 title claims abstract description 31
- 238000000034 method Methods 0.000 title claims abstract description 28
- 230000008569 process Effects 0.000 title claims abstract description 21
- 238000004146 energy storage Methods 0.000 title claims abstract description 15
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 47
- 239000012530 fluid Substances 0.000 claims abstract description 34
- 239000003292 glue Substances 0.000 claims abstract description 32
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 24
- 238000002347 injection Methods 0.000 claims abstract description 16
- 239000007924 injection Substances 0.000 claims abstract description 16
- 238000005498 polishing Methods 0.000 claims abstract description 4
- 238000005086 pumping Methods 0.000 claims abstract description 3
- 239000003921 oil Substances 0.000 claims description 45
- 239000002562 thickening agent Substances 0.000 claims description 17
- 239000003431 cross linking reagent Substances 0.000 claims description 16
- 239000000203 mixture Substances 0.000 claims description 12
- VSCWAEJMTAWNJL-UHFFFAOYSA-K aluminium trichloride Chemical compound Cl[Al](Cl)Cl VSCWAEJMTAWNJL-UHFFFAOYSA-K 0.000 claims description 8
- -1 butyl oleate sodium sulphate compounds Chemical class 0.000 claims description 8
- 238000006243 chemical reaction Methods 0.000 claims description 8
- 239000003638 chemical reducing agent Substances 0.000 claims description 8
- 239000004927 clay Substances 0.000 claims description 8
- XNGIFLGASWRNHJ-UHFFFAOYSA-N phthalic acid Chemical compound OC(=O)C1=CC=CC=C1C(O)=O XNGIFLGASWRNHJ-UHFFFAOYSA-N 0.000 claims description 8
- 239000003381 stabilizer Substances 0.000 claims description 8
- 239000002245 particle Substances 0.000 claims description 6
- 239000000654 additive Substances 0.000 claims description 5
- 230000000996 additive effect Effects 0.000 claims description 5
- NFAOATPOYUWEHM-UHFFFAOYSA-N 2-(6-methylheptyl)phenol Chemical compound CC(C)CCCCCC1=CC=CC=C1O NFAOATPOYUWEHM-UHFFFAOYSA-N 0.000 claims description 4
- 239000004971 Cross linker Substances 0.000 claims description 4
- 229920003171 Poly (ethylene oxide) Polymers 0.000 claims description 4
- GSEJCLTVZPLZKY-UHFFFAOYSA-N Triethanolamine Chemical compound OCCN(CCO)CCO GSEJCLTVZPLZKY-UHFFFAOYSA-N 0.000 claims description 4
- QCWXUUIWCKQGHC-UHFFFAOYSA-N Zirconium Chemical compound [Zr] QCWXUUIWCKQGHC-UHFFFAOYSA-N 0.000 claims description 4
- PRPAGESBURMWTI-UHFFFAOYSA-N [C].[F] Chemical compound [C].[F] PRPAGESBURMWTI-UHFFFAOYSA-N 0.000 claims description 4
- 125000001931 aliphatic group Chemical group 0.000 claims description 4
- 150000001768 cations Chemical group 0.000 claims description 4
- 239000007795 chemical reaction product Substances 0.000 claims description 4
- 239000000470 constituent Substances 0.000 claims description 4
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 4
- 238000010438 heat treatment Methods 0.000 claims description 4
- 239000003999 initiator Substances 0.000 claims description 4
- FBAFATDZDUQKNH-UHFFFAOYSA-M iron chloride Chemical compound [Cl-].[Fe] FBAFATDZDUQKNH-UHFFFAOYSA-M 0.000 claims description 4
- OJURWUUOVGOHJZ-UHFFFAOYSA-N methyl 2-[(2-acetyloxyphenyl)methyl-[2-[(2-acetyloxyphenyl)methyl-(2-methoxy-2-oxoethyl)amino]ethyl]amino]acetate Chemical compound C=1C=CC=C(OC(C)=O)C=1CN(CC(=O)OC)CCN(CC(=O)OC)CC1=CC=CC=C1OC(C)=O OJURWUUOVGOHJZ-UHFFFAOYSA-N 0.000 claims description 4
- UJVRJBAUJYZFIX-UHFFFAOYSA-N nitric acid;oxozirconium Chemical compound [Zr]=O.O[N+]([O-])=O.O[N+]([O-])=O UJVRJBAUJYZFIX-UHFFFAOYSA-N 0.000 claims description 4
- 229920002401 polyacrylamide Polymers 0.000 claims description 4
- 229920000642 polymer Polymers 0.000 claims description 4
- 150000003242 quaternary ammonium salts Chemical class 0.000 claims description 4
- 239000004094 surface-active agent Substances 0.000 claims description 4
- 238000010189 synthetic method Methods 0.000 claims description 4
- 229910052726 zirconium Inorganic materials 0.000 claims description 4
- 229940088644 n,n-dimethylacrylamide Drugs 0.000 claims description 3
- YLGYACDQVQQZSW-UHFFFAOYSA-N n,n-dimethylprop-2-enamide Chemical compound CN(C)C(=O)C=C YLGYACDQVQQZSW-UHFFFAOYSA-N 0.000 claims description 3
- 229920000747 poly(lactic acid) Polymers 0.000 claims description 3
- 239000004626 polylactic acid Substances 0.000 claims description 3
- 238000009835 boiling Methods 0.000 claims description 2
- 230000003196 chaotropic effect Effects 0.000 claims 1
- 239000007788 liquid Substances 0.000 abstract description 6
- 238000010276 construction Methods 0.000 description 12
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 description 6
- 239000004576 sand Substances 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000004519 manufacturing process Methods 0.000 description 5
- 238000011084 recovery Methods 0.000 description 5
- 239000010779 crude oil Substances 0.000 description 4
- 230000035699 permeability Effects 0.000 description 4
- 238000000502 dialysis Methods 0.000 description 3
- 238000005553 drilling Methods 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- WIBFFTLQMKKBLZ-SEYXRHQNSA-N n-butyl oleate Chemical group CCCCCCCC\C=C/CCCCCCCC(=O)OCCCC WIBFFTLQMKKBLZ-SEYXRHQNSA-N 0.000 description 3
- 229910052938 sodium sulfate Inorganic materials 0.000 description 3
- 235000011152 sodium sulphate Nutrition 0.000 description 3
- XQCFHQBGMWUEMY-ZPUQHVIOSA-N Nitrovin Chemical compound C=1C=C([N+]([O-])=O)OC=1\C=C\C(=NNC(=N)N)\C=C\C1=CC=C([N+]([O-])=O)O1 XQCFHQBGMWUEMY-ZPUQHVIOSA-N 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 125000000913 palmityl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 238000003825 pressing Methods 0.000 description 2
- 239000000047 product Substances 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 244000007835 Cyamopsis tetragonoloba Species 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000013329 compounding Methods 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 239000006071 cream Substances 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000007935 neutral effect Effects 0.000 description 1
- 230000008092 positive effect Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
- 210000005239 tubule Anatomy 0.000 description 1
- 239000000080 wetting agent Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
-
- 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
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
-
- 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
- Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
- Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Lubricants (AREA)
Abstract
The present invention relates to compact oil reservoir CO2Auxiliary energy-storage imbibition fracturing process includes the following steps: the seam stage: making complicated seam using pumping slippery water mode, and interval carries proppant polishing crack wall surface simultaneously；During seam, with fluid injection state CO2；The load fluid stage: it is initially injected slippery water, and interval carries proppant support on the neck crack simultaneously, and is added with efficient imbibition agent in slippery water；Secondly injection frozen glue, and interval carries proppant support nearly pit shaft area crack simultaneously；And when injecting slippery water or frozen glue, the initial stage does not carry proppant, slippery water or frozen glue as insulating liquid and injects pit shaft；In the load fluid stage, with fluid injection state CO2；The frozen glue that proppant is carried in pit shaft is all replaced into stratum with slippery water；Pressure break finishes, and boils in a covered pot over a slow fire well, starts open flow drain after pressure tends to be steady.The present invention improves stratum wetability by adding efficient imbibition agent in slippery water fracturing fluid.
Description
Technical field
The invention belongs to oilfield exploitation technical field more particularly to compact oil reservoir CO2Auxiliary energy-storage imbibition fracturing process.
Background technique
Compact oil reservoir has become the important energy source form taken over and produced in conventional energy resource increasing the storage.Currently, such oil reservoir is effective
Development tool is horizontal well or Encryption Well hydraulic fracturing, improves recovery ratio by improving the drainage volume of transformation reservoir.But
Generally existing validity period is short, the problems such as expected is not achieved in yield.The reason is that, compact oil reservoir permeability is low (being less than 10mD), hair
Tubule power becomes the main reason for restricting crude oil extraction.In addition, stratum energy is insufficient, fracturing fluid recovery (backflow) is not thorough and also results in pressure
It is undesirable to split effect.
Imbibition replacement technique be reservoir is changed into strongly hydrophilic by neutral or lipophilicity by the way that wetting agent is added, thus
Reduce capillary resistance, enabling entry well fluid, spontaneously imbibition enters in the subtle duct of host rock, replaces crude oil to greatly
In duct, the purpose for improving recovery ratio is realized.
108753272 A of patent CN disclose it is a kind of do not return discharge fracturing fluid and huff and puff oil recovery method with high imbibition rate,
Its low water-insoluble hydroxypropyl guar used can also damage stratum in actual use.
Therefore, these problems are based on, a kind of CO is provided2Auxiliary energy-storage is efficiently seeped by adding in slippery water fracturing fluid
Vapor improves the imbibition fracturing process of stratum wetability, has important practical significance.
Summary of the invention
It is an object of the invention to overcome the deficiencies of the prior art and provide a kind of CO2Auxiliary energy-storage, by smooth hydraulic pressure
It splits and adds efficient imbibition agent in liquid, improve the imbibition fracturing process of stratum wetability.
The present invention solves its technical problem and adopts the following technical solutions to achieve:
Compact oil reservoir CO2Auxiliary energy-storage imbibition fracturing process, includes the following steps:
The seam stage: complicated seam is made using pumping slippery water mode, and interval carries proppant polishing crack wall surface simultaneously；
During seam, with fluid injection state CO2, improve stratum energy；
The load fluid stage: it is initially injected slippery water, and interval carries proppant support on the neck crack, and slippery water simultaneously
In be added with efficient imbibition agent；Secondly injection frozen glue, and interval carries proppant support nearly pit shaft area crack simultaneously, establishes high
Permeability flow-guiding channel；And when injecting slippery water or frozen glue, the initial stage does not carry proppant, and slippery water or frozen glue are made
Pit shaft is injected for insulating liquid；In the load fluid stage, with fluid injection state CO2, improve stratum energy；
The frozen glue that proppant is carried in pit shaft is all replaced into stratum with slippery water；
Pressure break finishes, and boils in a covered pot over a slow fire well, starts open flow drain after pressure tends to be steady, until must not arbitrarily close before well head no pressure
Well；Wherein, boiling in a covered pot over a slow fire the well time is 8-20 days.
Further, efficient imbibition agent is butyl oleate sodium sulphate and polyoxyethylene isooctyl phenol ether according to mass ratio 1:
The mixture of 8 compounding compositions；The slippery water includes following component: 0.1% drag reducer, 2% clay stabilizer, 0.5% row of helping
Agent and clear water, and the above constituent content is the mass percent on the basis of clear water, clay stabilizer is organic expansion-resisting agent,
Cleanup additive is cation fluorine carbon surface active agent, and drag reducer is anion-polyacrylamide；The frozen glue is poly- for low molecular weight
Close object frozen glue, the frozen glue is to be formed after low molecular weight thickening agent and 0.025% cross-linking agents, the content of crosslinking agent for
Mass percent on the basis of low molecular weight thickening agent, and crosslinking agent is organic zirconium crosslinker, low molecular weight thickening agent molecular weight
Less than 5,000,000.
Further, the low molecular weight thickening agent is by N,N-DMAA, terminal carboxylicization aliphatic poly cream
Acid and hexadecanyl trimethyl quaternary ammonium salt 8:5:1 in mass ratio, using azo-bis-isobutyl cyanide dimethyl ester as initiator, in reaction temperature
It is obtained under the conditions of 65 DEG C of degree, reaction 3h；The crosslinking agent synthetic method are as follows: by water, triethanolamine, phthalic acid, iron chloride
It is uniformly mixed with aluminium chloride according to mass ratio 70:5:5:3:2, heating mixture temperature rises to 65 DEG C, adds 15 parts by weight
Zirconyl nitrate；6-7h is reacted, is finally cooled to room temperature reaction products therefrom.
Further, the method is suitable for pressure resistance 100MPa fracture well head.
Further, open flow drain system is as follows after pressure break: if oil pressure 7-10MPa, being controlled using Φ 3mm oil nozzle
The row of returning；If oil pressure 5-7MPa, the row of returning is controlled using Φ 4mm oil nozzle；If oil pressure 3-5MPa, the row of returning is controlled using Φ 6mm oil nozzle；If
Oil pressure is lower than 3MPa, controls the row of returning using Φ 8mm oil nozzle.
Further, the proppant selects at least one of 40-70 mesh, high-strength ceramsite particle of 30-50 mesh partial size.
Further, the proppant carried when the load fluid stage injection slippery water is the height of partial size 40-70 mesh partial size
Intensity haydite particles；The proppant carried when the load fluid stage injection frozen glue is the high-intensitive pottery of partial size 30-50 mesh partial size
Grain particle.
Further, the proppant concentration of the load fluid stage injection gradually increases.
The advantages and positive effects of the present invention are:
1, the present invention makes complicated seam using low viscosity slippery water huge discharge in pad stage, in combination with Proppant Slugs
Technology polishing crack wall surface, reduces construction pump pressure；In the seam stage and the sand stage is taken with fluid injection state CO2, can effectively improve ground
The energy of layer, promotes the dissolution and flowing of formation crude oil；
2, the present invention improves stratum wetability, benefit by adding efficient imbibition agent in taking sand stage slippery water fracturing fluid
Crude oil is produced with capillary force, further increases oil recovery factor；
3, low-molecular weight polymer thickener used in the present invention has the characteristics that, pressure break small, labile using concentration
After can fast degradation, it is small to formation contaminant.
Specific embodiment
Firstly, it is necessary to which explanation, illustrates specific structure of the invention, feature and excellent for by way of example below
Point etc., however what all descriptions were intended merely to be illustrated, and should not be construed as to present invention formation any restrictions.This
Outside, any single technical characteristic for being described by or implying in each embodiment mentioned by this paper, still can be in these technologies spy
Continue any combination between sign (or its equivalent) or delete, to obtain this hair that may do not referred to directly herein
Bright more other embodiments.
It should be noted that term used herein above is merely to describe specific embodiment, and be not intended to restricted root
According to the illustrative embodiments of the application.As used herein, unless the context clearly indicates otherwise, otherwise singular
Also it is intended to include plural form, in addition, term " includes " and " having " and their any deformation, it is intended that covering is not arranged
His includes, for example, the process, method, system, product or equipment for containing a series of steps or units are not necessarily limited to clearly
Those of list step or unit, but may include be not clearly listed or for these process, methods, product or equipment
Intrinsic other step or units.
It should be noted that in the absence of conflict, the features in the embodiments and the embodiments of the present application can phase
Mutually combination.
Embodiment 1
W1 well is Chaidamu Basin, Qinghai Province a bite straight well, finishing drilling well depth 1980m, purpose of horizon totally 5 substratum, core intersection
8.7m, average pore 10.49%, mean permeability 33.92mD, average oil saturation 13.41%；Offset well a brittleness index
Average value is 46.9%, and the brittleness index average value of offset well b is 39%, this well has certain compressibility.
The well in May, 2008 goes into operation, 0.19 ton of oil-producing of initial stage day, and aqueous 72.74%；Dead chick in June, 2008, the perforations adding day before yesterday
0.18 ton of oil-producing, aqueous 68.66%；3.36 tons of oil-producing of day after perforations adding, aqueous 7.04%；At present 0.49 ton of oil-producing of the well day, contain
Water 12.42%.
To improve the well production, back-up sand blocks top payzone.Pressure break is carried out to lower part payzone.In order to improve crack complexity journey
Degree, fracturing fluid become viscosity fracturing fluid using slippery water and low concentration frozen glue, sand are added to take multistage injection mode.It is added in fracturing fluid
Efficient imbibition agent, improves oil flow channel, is produced oil using capillary force action.Construction pump note program, kind of liquid plus support
The parameters such as agent concentration, dialysis agent concentration are as shown in table 1.Well is boiled in a covered pot over a slow fire after pressing crack construction.
1 W1 well construction of table pump note program
Wherein, in the construction process, discharge capacity (slippery water or frozen glue discharge capacity) reaches 8m3/ min injects pressure break in construction altogether
Liquid 3086m3, wherein frozen glue 295m3, slippery water 2791m3；30-50 mesh high-strength ceramsite 20m3, 40-70 mesh high-strength ceramsite
50m3, efficient dialysis agent 16800kg.Stewing well 16 days, return lifting rate 518.5m3, the row of returning leads 16.8%.
Wherein, efficient imbibition agent is that butyl oleate sodium sulphate and polyoxyethylene isooctyl phenol ether are multiple according to mass ratio 1:8
Mixture with composition；The slippery water includes following component: 0.1% drag reducer, 2% clay stabilizer, 0.5% cleanup additive and
Clear water, and the above constituent content is the mass percent on the basis of clear water, clay stabilizer is organic expansion-resisting agent, the row of helping
Agent is cation fluorine carbon surface active agent, and drag reducer is anion-polyacrylamide；The frozen glue is low-molecular weight polymer
Frozen glue, for the frozen glue to be formed after low molecular weight thickening agent and 0.025% cross-linking agents, the content of crosslinking agent is with low point
Mass percent on the basis of son amount thickening agent, and crosslinking agent is organic zirconium crosslinker, low molecular weight thickening agent molecular weight is less than
5000000；Low molecular weight thickening agent is by N, N- dimethylacrylamide, terminal carboxylicization aliphatic poly lactic acid and cetyl front three
Based quaternary ammonium salt 8:5:1 in mass ratio, using azo-bis-isobutyl cyanide dimethyl ester as initiator, in 65 DEG C of reaction temperature, reaction 3h item
It is obtained under part；Crosslinking agent synthetic method are as follows: by water, triethanolamine, phthalic acid, iron chloride and aluminium chloride according to mass ratio
70:5:5:3:2 is uniformly mixed, and heating mixture temperature rises to 65 DEG C, adds the zirconyl nitrate of 15 parts by weight；6-7h is reacted,
Finally reaction products therefrom is cooled to room temperature.
It should be noted that in the construction process, as long as meeting equipment pressure requirements, operational discharge capacity is the bigger the better.
After pressure break, (16 days) interior daily average oil production 8.52t during formation testing, average daily fluid production rate 10.28t are average aqueous
Rate 17.1%；Fracturing effect is preferable, reaches geological design requirement.
Embodiment 2
W2 well is the new finishing drilling straight well of Jilin Oil Field a bite, finishing drilling well depth 2658m, purpose of horizon totally 4 substratum, core intersection
6.8m, average pore 6.52%, mean permeability 15.7mD, average oil saturation 16.88%.This well brittleness index is average
Value is 68.6%, and compressibility is higher.
In order to improve crack complexity, fracturing fluid becomes viscosity fracturing fluid using slippery water and low concentration frozen glue, sand is added to adopt
Take multistage injection mode.Efficient imbibition agent is added in fracturing fluid, improves oil flow channel, is produced oil using capillary force action.
Construction pump note program, adds the parameters such as sand concentration, dialysis agent concentration as shown in table 2 at kind of liquid.Well is boiled in a covered pot over a slow fire after pressing crack construction.
2 W2 well construction of table pump note program
Wherein, in the construction process, discharge capacity (slippery water or frozen glue discharge capacity) reaches 8m3/ min, injects fracturing fluid altogether
2536m3, wherein frozen glue 195m3, slippery water 2341m3；30-50 mesh high-strength ceramsite 15m3, 40-70 mesh high-strength ceramsite 40m3。
Efficient imbibition agent dosage 12600Kg (whether correct checking lower data).Stewing well 14 days.Return lifting rate 320.8m3, the row of returning leads
13.7%.
It should be noted that in the construction process, as long as meeting equipment pressure requirements, operational discharge capacity is the bigger the better.
Wherein, efficient imbibition agent is that butyl oleate sodium sulphate and polyoxyethylene isooctyl phenol ether are multiple according to mass ratio 1:8
Mixture with composition；The slippery water includes following component: 0.1% drag reducer, 2% clay stabilizer, 0.5% cleanup additive and
Clear water, and the above constituent content is the mass percent on the basis of clear water, clay stabilizer is organic expansion-resisting agent, the row of helping
Agent is cation fluorine carbon surface active agent, and drag reducer is anion-polyacrylamide；The frozen glue is low-molecular weight polymer
Frozen glue, for the frozen glue to be formed after low molecular weight thickening agent and 0.025% cross-linking agents, the content of crosslinking agent is with low point
Mass percent on the basis of son amount thickening agent, and crosslinking agent is organic zirconium crosslinker, low molecular weight thickening agent molecular weight is less than
5000000；Low molecular weight thickening agent is by N, N- dimethylacrylamide, terminal carboxylicization aliphatic poly lactic acid and cetyl front three
Based quaternary ammonium salt 8:5:1 in mass ratio, using azo-bis-isobutyl cyanide dimethyl ester as initiator, in 65 DEG C of reaction temperature, reaction 3h item
It is obtained under part；Crosslinking agent synthetic method are as follows: by water, triethanolamine, phthalic acid, iron chloride and aluminium chloride according to mass ratio
70:5:5:3:2 is uniformly mixed, and heating mixture temperature rises to 65 DEG C, adds the zirconyl nitrate of 15 parts by weight；6-7h is reacted,
Finally reaction products therefrom is cooled to room temperature.
After pressure break, (19 days) interior daily average oil production 6.75t during formation testing, average daily fluid production rate 8.36t, average moisture content
19.3%.Fracturing effect is preferable, reaches geological design requirement.
Above embodiments describe the invention in detail, but content is only the preferred embodiment of the present invention, no
It can be believed to be used to limit the scope of the invention.Any changes and modifications in accordance with the scope of the present application,
It should still fall within the scope of the patent of the present invention.
Claims (8)
1. compact oil reservoir CO2Auxiliary energy-storage imbibition fracturing process, characterized by the following steps:
The seam stage: complicated seam is made using pumping slippery water mode, and interval carries proppant polishing crack wall surface simultaneously；It is making
During seam, with fluid injection state CO2, improve stratum energy；
The load fluid stage: it is initially injected slippery water, and interval carries proppant support on the neck crack simultaneously, and adds in slippery water
Added with efficient imbibition agent；Secondly injection frozen glue, and interval carries proppant support nearly pit shaft area crack simultaneously, establishes Thief zone
Rate flow-guiding channel；And injecting slippery water or when frozen glue, the initial stage does not carry proppant, slippery water or frozen glue be used as every
Chaotropic injects pit shaft；In the load fluid stage, with fluid injection state CO2, improve stratum energy；
The frozen glue that proppant is carried in pit shaft is all replaced into stratum with slippery water；
Pressure break finishes, and boils in a covered pot over a slow fire well, starts open flow drain after pressure tends to be steady, until must not random closing well before well head no pressure；Its
In, boiling in a covered pot over a slow fire the well time is 8-20 days.
2. compact oil reservoir CO according to claim 12Auxiliary energy-storage imbibition fracturing process, it is characterised in that: efficient imbibition agent
It is the mixture that butyl oleate sodium sulphate compounds composition with polyoxyethylene isooctyl phenol ether according to mass ratio 1:8；It is described smooth
Water includes following component: 0.1% drag reducer, 2% clay stabilizer, 0.5% cleanup additive and clear water, and the above constituent content is
Mass percent on the basis of clear water, clay stabilizer are organic expansion-resisting agent, and cleanup additive is cation fluorine carbon surface active
Agent, drag reducer are anion-polyacrylamide；The frozen glue is low-molecular weight polymer frozen glue, and the frozen glue is low molecular weight
It is formed after thickening agent and 0.025% cross-linking agents, the content of crosslinking agent is the quality on the basis of low molecular weight thickening agent
Percentage, and crosslinking agent is organic zirconium crosslinker, low molecular weight thickening agent molecular weight is less than 5,000,000.
3. compact oil reservoir CO according to claim 22Auxiliary energy-storage imbibition fracturing process, it is characterised in that: the low molecule
Thickening agent is measured by N, N- dimethylacrylamide, terminal carboxylicization aliphatic poly lactic acid and hexadecanyl trimethyl quaternary ammonium salt press matter
Amount is than 8:5:1, using azo-bis-isobutyl cyanide dimethyl ester as initiator, obtains under the conditions of 65 DEG C of reaction temperature, reaction 3h；It is described
Crosslinking agent synthetic method are as follows: by water, triethanolamine, phthalic acid, iron chloride and aluminium chloride according to mass ratio 70:5:5:3:2
It is uniformly mixed, heating mixture temperature rises to 65 DEG C, adds the zirconyl nitrate of 15 parts by weight；6-7h is reacted, it finally will reaction
Products therefrom is cooled to room temperature.
4. compact oil reservoir CO according to claim 12Auxiliary energy-storage imbibition fracturing process, it is characterised in that: the method is suitable
For pressure-resistant 100MPa fracture well head.
5. compact oil reservoir CO according to claim 12Auxiliary energy-storage imbibition fracturing process, it is characterised in that: after pressure break
Open flow drain system is as follows: if oil pressure 7-10MPa, controlling the row of returning using Φ 3mm oil nozzle；If oil pressure 5-7MPa, using Φ 4mm
Oil nozzle controls the row of returning；If oil pressure 3-5MPa, the row of returning is controlled using Φ 6mm oil nozzle；If oil pressure is lower than 3MPa, using Φ 8mm oil nozzle
Control the row of returning.
6. compact oil reservoir CO according to claim 12Auxiliary energy-storage imbibition fracturing process, it is characterised in that: the proppant
Select at least one of 40-70 mesh, high-strength ceramsite particle of 30-50 mesh partial size.
7. compact oil reservoir CO according to claim 62Auxiliary energy-storage imbibition fracturing process, it is characterised in that: the load fluid
Stage injects the high-strength ceramsite particle that the proppant carried when slippery water is partial size 40-70 mesh partial size；The load fluid stage
The proppant carried when injecting frozen glue is the high-strength ceramsite particle of partial size 30-50 mesh partial size.
8. compact oil reservoir CO according to claim 72Auxiliary energy-storage imbibition fracturing process, it is characterised in that: the load fluid
The stage proppant concentration of injection gradually increases.
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| CN115163020A (en) * | 2022-07-01 | 2022-10-11 | 中国石油化工股份有限公司 | Shale oil energy storage, oil displacement, pressure control and crack formation fracturing process |
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Application publication date: 20190827 |