CN106350043B - Complex Temporary Blocking agent and Complex Temporary Blocking method for temporarily blocking up in turnaround fracture - Google Patents
Complex Temporary Blocking agent and Complex Temporary Blocking method for temporarily blocking up in turnaround fracture Download PDFInfo
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- CN106350043B CN106350043B CN201610584258.XA CN201610584258A CN106350043B CN 106350043 B CN106350043 B CN 106350043B CN 201610584258 A CN201610584258 A CN 201610584258A CN 106350043 B CN106350043 B CN 106350043B
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- temporary blocking
- complex temporary
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- 230000000903 blocking effect Effects 0.000 title claims abstract description 34
- 239000002981 blocking agent Substances 0.000 title claims abstract description 33
- 238000000034 method Methods 0.000 title claims abstract description 31
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 210
- 239000002245 particle Substances 0.000 claims description 24
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 21
- 230000015572 biosynthetic process Effects 0.000 claims description 17
- NIXOWILDQLNWCW-UHFFFAOYSA-M Acrylate Chemical compound [O-]C(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-M 0.000 claims description 10
- 229920005989 resin Polymers 0.000 claims description 10
- 239000011347 resin Substances 0.000 claims description 10
- 238000007789 sealing Methods 0.000 claims description 10
- 229920002134 Carboxymethyl cellulose Polymers 0.000 claims description 9
- 239000001768 carboxy methyl cellulose Substances 0.000 claims description 9
- 235000010948 carboxy methyl cellulose Nutrition 0.000 claims description 9
- 239000008112 carboxymethyl-cellulose Substances 0.000 claims description 9
- 229920002401 polyacrylamide Polymers 0.000 claims description 9
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims description 8
- 229920001577 copolymer Polymers 0.000 claims description 7
- 108010010803 Gelatin Proteins 0.000 claims description 4
- 239000008273 gelatin Substances 0.000 claims description 4
- 229920000159 gelatin Polymers 0.000 claims description 4
- 235000019322 gelatine Nutrition 0.000 claims description 4
- 235000011852 gelatine desserts Nutrition 0.000 claims description 4
- 125000002057 carboxymethyl group Chemical group [H]OC(=O)C([H])([H])[*] 0.000 claims description 3
- 230000009466 transformation Effects 0.000 claims description 3
- 229920000663 Hydroxyethyl cellulose Polymers 0.000 claims description 2
- 239000004354 Hydroxyethyl cellulose Substances 0.000 claims description 2
- 229920002472 Starch Polymers 0.000 claims description 2
- 235000019447 hydroxyethyl cellulose Nutrition 0.000 claims description 2
- 239000003077 lignite Substances 0.000 claims description 2
- 229920006149 polyester-amide block copolymer Polymers 0.000 claims description 2
- 239000008107 starch Substances 0.000 claims description 2
- 235000019698 starch Nutrition 0.000 claims description 2
- 229920001732 Lignosulfonate Polymers 0.000 claims 1
- 239000004698 Polyethylene Substances 0.000 claims 1
- -1 polyethylene Polymers 0.000 claims 1
- 229920000573 polyethylene Polymers 0.000 claims 1
- 239000003129 oil well Substances 0.000 abstract description 3
- 238000012360 testing method Methods 0.000 description 15
- 230000000694 effects Effects 0.000 description 14
- 238000002347 injection Methods 0.000 description 12
- 239000007924 injection Substances 0.000 description 12
- 230000000052 comparative effect Effects 0.000 description 9
- 239000012530 fluid Substances 0.000 description 8
- 238000010276 construction Methods 0.000 description 7
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 5
- 238000004090 dissolution Methods 0.000 description 5
- 238000011156 evaluation Methods 0.000 description 5
- 238000005259 measurement Methods 0.000 description 5
- 239000000203 mixture Substances 0.000 description 5
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 239000000463 material Substances 0.000 description 4
- 239000011435 rock Substances 0.000 description 4
- 229910001870 ammonium persulfate Inorganic materials 0.000 description 3
- 150000001875 compounds Chemical class 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- 239000004372 Polyvinyl alcohol Substances 0.000 description 2
- 239000006004 Quartz sand Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 239000000654 additive Substances 0.000 description 2
- 230000000996 additive effect Effects 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 239000000835 fiber Substances 0.000 description 2
- 239000003292 glue Substances 0.000 description 2
- 230000007062 hydrolysis Effects 0.000 description 2
- 238000006460 hydrolysis reaction Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 229920002451 polyvinyl alcohol Polymers 0.000 description 2
- 239000000843 powder Substances 0.000 description 2
- 238000003825 pressing Methods 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 239000002994 raw material Substances 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- ZAMOUSCENKQFHK-UHFFFAOYSA-N Chlorine atom Chemical compound [Cl] ZAMOUSCENKQFHK-UHFFFAOYSA-N 0.000 description 1
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 235000019282 butylated hydroxyanisole Nutrition 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 239000000460 chlorine Substances 0.000 description 1
- 229910052801 chlorine Inorganic materials 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 239000008139 complexing agent Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 229920001971 elastomer Polymers 0.000 description 1
- 229920006351 engineering plastic Polymers 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 239000000945 filler Substances 0.000 description 1
- 239000012065 filter cake Substances 0.000 description 1
- 238000011010 flushing procedure Methods 0.000 description 1
- 239000000499 gel Substances 0.000 description 1
- 239000008187 granular material Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000011591 potassium Substances 0.000 description 1
- 229910052700 potassium Inorganic materials 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000004575 stone Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000006277 sulfonation reaction Methods 0.000 description 1
Classifications
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Chemical & Material Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Sealing Material Composition (AREA)
Abstract
The Complex Temporary Blocking agent that the present invention provides a kind of for temporarily blocking up in turnaround fracture comprising diverting agent a and diverting agent b, the diverting agent a are selected from rigid diverting agent, and the diverting agent b is selected from dilatancy diverting agent.The Complex Temporary Blocking method used in the turnaround fracture of oil field that the present invention also provides one kind, including diverting agent a and diverting agent b are sequentially injected in oil well crack.The present invention is by selecting rigid diverting agent and intumescent diverting agent, use that it is dexterously arranged in pairs or groups to substantially increase the service efficiency and refracturing success rate of diverting agent.
Description
Technical field
The present invention relates to increasing yield of oil and natural gas technical fields, and in particular to used in the temporary stifled turnaround fracture it is compound temporarily
Blocking agent and a kind of Complex Temporary Blocking method.
Background technique
Oil field fracturing diverting agent mainly has water-soluble granular diverting agent and fibrous type diverting agent at present, and water-soluble granular is temporary
Blocking agent is divided into inflatable and can not intumescent.In addition to thering are some report particle diverting agents and fibrous type diverting agent to be used in combination, temporarily
Blocking agent is mostly single use.
Cracky production method is proposed in Chinese patent application CN103835691, after crack presses off completion, is added
High-intensitive water-soluble granular diverting agent, to block the sealing in crack, until completing preset Number of Fractures.Chinese patent application
A kind of biodegradable fiber and linear glue and proppant are mentioned in CN103615228 as stifled fracturing fluid temporary in seam, are formed branch and are split
Seam.A kind of ground cross-linking type viscoelastic particle diverting agent is mentioned in Chinese patent application CN102020984, in borehole and Thief zone
Band forms filter cake bridge blinding, finally promotes newly to stitch generation.A kind of underground crosslinked type powder is invented in Chinese patent application CN102344788
End or granular pattern diverting agent, realize that net horizontal section effectively blocks, and realize controllable rubber breaking by capsule-type gel breaker.
It is above-mentioned in the prior art be mostly carried out using single diverting agent or diverting agent mixture temporary stall to.So
And be found by experiment that, when only a kind of particle diverting agent or fiber diverting agent, it is difficult to while playing bridge formation enrichment and being formed
The effect of fine and close plugged zone.Unexpansive particle diverting agent is such as used only, it is difficult to form fine and close plugged zone；Such as it is used only inflatable
Grain, because its softness is difficult to enrichment of building bridge.Therefore, exploitation has the diverting agent and temporary blocking method of the temporarily stifled effect improved, for stone
It is to be badly in need of, be of great significance for oil exploitation.
Summary of the invention
The purpose of the present invention is to provide a kind of Complex Temporary Blocking agent that can be improved the temporarily stifled validity in oilfield exploitation with
And the Complex Temporary Blocking method using the Complex Temporary Blocking agent.
According to an aspect of the present invention, a kind of Complex Temporary Blocking agent for temporarily blocking up in turnaround fracture is provided comprising temporarily
Blocking agent a and diverting agent b, the diverting agent a are selected from rigid diverting agent, and the diverting agent b is selected from intumescent diverting agent.The present invention mentions
The Complex Temporary Blocking agent of confession is it can be appreciated that include the diverting agent packet of diverting agent a and diverting agent b.
The intumescent diverting agent, which refers to, meets the diverting agent material that water energy enough expands.In the present invention, it is preferred to described
Intumescent diverting agent expands 2-10 times, preferably 3-6 times in 2h in water.The rigidity diverting agent is relative to intumescent diverting agent
For, refer generally to non-expansion type diverting agent.
As previously mentioned, using single diverting agent in the prior art, or it is added at one time formula diverting agent, it tends to be difficult to same
When play the role of building bridge and enrichment and form fine and close plugged zone.
The present invention is realized efficiently temporarily by the composite usage of non-expansion type particle diverting agent and intumescent particle diverting agent
Stifled purpose.Wherein, diverting agent a plays the role of enrichment of building bridge, and diverting agent b then can form the base built bridge in diverting agent a
It is further blocked on plinth and forms fine and close plugged zone, to improve temporarily stifled validity.
According to the present invention, the diverting agent a can be wooden selected from Soluble acrylate's resin, gelatin, sulfonated gilsonite, sulfonation
One of element, sulfonated lignite, polyvinyl alcohol and polyesteramide are a variety of, preferably gelatin, sulfonated gilsonite and Soluble acrylate
At least one of resin, more preferable Soluble acrylate's resin.Be suitable for diverting agent a it is aforementioned can be made by oneself for material selection or
Commercially available from person.
According to the present invention, the diverting agent b can be fine selected from carboxymethyl starch, partially hydrolyzed polyacrylamide (PHPA), carboxymethyl
Dimension element, the copolymer of carboxymethyl cellulose and acrylamide, hydroxyethyl cellulose and acrylamide one of copolymer or
It is a variety of, the preferred copolymer of partially hydrolyzed polyacrylamide (PHPA) and/or carboxymethyl cellulose and acrylamide, more preferable partial hydrolysis
Polyacrylamide.Wherein, the preferred carboxymethyl cellulose with high degree of the carboxymethyl cellulose.It is suitable for the aforementioned of diverting agent b
It can be made by oneself for material selection or commercially available.
According to the preferred embodiment of the present invention, in the Complex Temporary Blocking agent, the weight of the diverting agent a and diverting agent b
Amount is than being (5-10): 1, preferably (5-8): 1, more preferable (5-6): 1.
According to the preferred embodiment of the present invention, the average grain diameter ratio of the diverting agent a and diverting agent b is (1.5-5): 1,
It is preferred that (2-4): 1.In the proportional region, diverting agent a can more fully be filled into the hole pattern of diverting agent b and carry out richness
Collection forms fine and close plugged zone.
According to the preferred embodiment of the present invention, the particle size of the diverting agent a is 2-20 mesh, preferably 4-10 mesh；Institute
The particle size for stating diverting agent b is 4-20 mesh, preferably 6-20 mesh.
According to the preferred embodiment of the present invention, 2-10 times of the expansion of (room temperature) 2h inner volume in water of the diverting agent b, it is excellent
Select 3-6 times.Through testing, the present invention is by selecting such diverting agent b, and especially arrange in pairs or groups a certain amount of above-mentioned diverting agent a, Neng Gouqi
To good temporarily stifled effect.
, according to the invention it is preferred to which the water insoluble matter content of the Complex Temporary Blocking agent is 7wt% hereinafter, it is preferred that 5wt% or less.
Water insoluble matter content is excessively high to cause possible permanent damage for blocking stratum.
In some preferred embodiments of the invention, the complexing agent is added to 30-120 DEG C of water with the amount of 2wt%
In solution, dissolution rate when 2h is 93% or more, preferably 95% or more；Additive includes 0.5-2wt% chlorine in the aqueous solution
Change potassium, 2-5wt% butylated hydroxy anisole (BHA) and one of 1-10%wt% hydrochloric acid and 0.05-2wt% ammonium persulfate or
It is several.
In above-mentioned additive, for example, when in water be added 0.05-2wt% ammonium persulfate when, make diverting agent a and b in low temperature
When dissolution rate improve, thus guarantee at different temperature can by diverting agent largely dissolve.
In order to reach best temporarily stifled effect, in a preferred embodiment of the invention, the Complex Temporary Blocking agent is in use,
Diverting agent a and diverting agent b sequentially inject in formation fracture.
According to the second aspect of the invention, provide it is a kind of for temporarily blocking up the Complex Temporary Blocking method of turnaround fracture, including
The Complex Temporary Blocking agent as described above provided according to the present invention is applied in the oil-well strata crack temporarily blocked up.
According to the preferred embodiment of the present invention, in temporary stifled program, diverting agent a is injected in formation fracture first, so
Diverting agent b is injected in formation fracture again afterwards.
The present invention is enriched with by building bridge first with non-expansion type particle diverting agent, then passes through intumescent particle diverting agent
It further blocks and forms fine and close plugged zone to realize efficiently temporarily stifled purpose.
The bridging action of rigid diverting agent can be after the passway that crack mouthful or proppant are formed be detained gradually
Enrichment, but the shortcomings that rigid diverting agent is that airtightness is not strong, can not form fine and close plugged zone, cause steering pressure not high, weight
Multiple pressure break is also difficult to success.If inflatable diverting agent is used alone, due to inflatable diverting agent, it has deformability, leads to it
Can not be formed bridge formation or envelope enrichment slowly, cause largely may expand diverting agent with fracturing fluid inflow stratum depths and not
To the effect of closure.In the methods of the invention, it is formed by add on plugged zone in rigid diverting agent and can form fine and close envelope
The inflatable diverting agent of blocking layer, the two are used cooperatively the service efficiency and refracturing success rate for substantially increasing diverting agent.
According to the present invention, in provided method, the usage amount (weight) of diverting agent a and diverting agent b are than being preferably (5-
10): 1, more preferable (5-8): 1, particularly preferred (5-6): 1.
An outstanding advantage of the invention is, by the way that formation fracture is successively added in selected diverting agent a and diverting agent b
Middle carry out fracturing work, it is only necessary to which the diverting agent a of relatively small amount can reach higher plugging effect, can greatly save raw material
Dosage improves the utilization efficiency of material, has saved cost.
Preferred embodiment according to the method for the present invention, the dosage of Complex Temporary Blocking agent are the temporarily blocking layer for making to be formed (before expansion)
With a thickness of 8-15mm, preferably 9-12mm.
The temporarily blocking layer formed according to the method for the present invention has the plugging strength significantly improved, and thickness is in 10mm or so, such as 9-
11mm range, plugging strength can reach 40MPa.
As it can be seen that the appropriate collocation by diverting agent a and diverting agent b uses, the present invention is not needed using a large amount of diverting agent,
It can be obtained preferable plugging effect.
Turnaround fracture and sealing are temporarily temporarily blocked up in the stifled main parting of turnaround fracture temporarily blocks up turnaround fracture.It provides according to the present invention
Temporarily stifled turnaround fracture and sealing temporarily block up turnaround fracture Complex Temporary Blocking method in stitching.Preferably, the temporary stall of sealing to
In pressure break, before implementing diverting agent a injection, proppant is first injected in crack.
For turnaround fracture in stitching, after crack presses off, at this time at a big channel in seam, if diverting agent partial size is smaller
Or it is relatively soft, they will enter stratum depths with fracturing fluid.Certain partial size rigidity diverting agent is added at this time, in crack
To build bridge, plugged zone is formed, but there are gaps between rigid particles.Inflatable diverting agent is added later, may expand temporarily stifled
Agent at the bridge formation of rigid diverting agent on be progressively enriched with and expand bonding, form fine and close plugged zone, the formation region of high stress in crack,
To generate new branch crack or link up more microcracks, complex fracture network is formed, transformation volume is improved.
For sealing turnaround fracture, such as during refracturing, first presses off, extends old crack and proppant is added
(such as quartz sand) is to activate old seam.Rigid diverting agent is added later, due to previously supported dose of presence, rigid diverting agent is being propped up
Support the enrichment of agent end face.Inflatable diverting agent is reinjected, may expand diverting agent, gradually expansion is viscous at the bridge formation of rigid diverting agent again
Knot forms fine and close plugged zone, and fracturing fluid enters the region of high stress, and new stitch is promoted to generate, and draining area is not employed in communication, reaches raising
The purpose of recovery ratio.
A specific embodiment according to the present invention, the Complex Temporary Blocking method include: the pump note journey in pressing crack construction
In sequence, by Soluble acrylate's resin particle injection formation fracture of 5-10 mesh, then the partial hydrolysis of 10-20 mesh is gathered again
Acrylamide particle injects in formation fracture；Soluble acrylate's resin particle and the partially hydrolyzed polyacrylamide (PHPA)
The weight ratio of grain is (4.5-5.5): 1, overall thickness 9-12mm.
In accordance with a further aspect of the present invention, Complex Temporary Blocking method as described above according to the present invention is provided to repeat in old well
Pressure break, unconventional reservoir volume fracturing (or seam network pressure is split), straight well separate stratum fracfturing, horizontal well fracturing and complex situations well
Application in transformation.Using method of the invention, in fracturing process, rigid diverting agent plays bridging action, may expand temporarily stifled
Agent forms fine and close closure at bridge formation, makes pressure rise, to open new seam.
The present invention splits oil well by selecting rigid diverting agent and intumescent diverting agent, and use that it is dexterously arranged in pairs or groups
The plugged zone for having suitable rigidity and compactness is formed in seam, and efficient temporary stifled performance is realized with simple diverting agent formula.It is logical
Suitably being used cooperatively for two kinds of diverting agents is crossed, the usage amount of raw material is reduced, substantially increases the service efficiency and again of diverting agent
Multiple pressure break success rate.
Detailed description of the invention
Fig. 1 is that injection pressure changes over time figure in Complex Temporary Blocking agent sealing characteristics evaluation test in embodiment 1.
Fig. 2 is that injection pressure changes over time figure in the evaluation test of diverting agent sealing characteristics in comparative example 1.
Fig. 3 is that injection pressure changes over time figure in the evaluation test of diverting agent sealing characteristics in comparative example 3.
Fig. 4 is that injection pressure changes over time figure in the evaluation test of diverting agent sealing characteristics in comparative example 4.
Fig. 5 is the construction curve figure of embodiment 5.
Specific embodiment
With reference to the accompanying drawing, by specific embodiment, the present invention is described further, it should be appreciated that model of the invention
It encloses and is not limited to this.
Embodiment 1
With Soluble acrylate's resin (Nanjing Shou Su special engineering plastics Products Co., Ltd) for diverting agent a, by its powder
It is broken, screen out the particle of 5-10 mesh；With partially hydrolyzed polyacrylamide (PHPA) (Beijing Xitao Development Tech Co., Ltd.) for diverting agent
B screens out the particle of 10-20 mesh, diverting agent a and b constitute Complex Temporary Blocking agent 1 by crushing.
Diverting agent a and diverting agent b are respectively put into water, diverting agent a hardly expands in 2h, and diverting agent b expansion is about
3.2 again.
In the water for the HCl being put at 40 DEG C containing 2wt% after diverting agent a and diverting agent b is mixed with weight ratio 5: 1,2 is small
Constantly, dissolution rate reaches 96%.The water insoluble matter content of mixture that measurement diverting agent a and diverting agent b weight ratio are 5: 1 is
4.5wt%.
Using rock core fluidity test instrument (Jiangsu Huaan Science Research Instrument Co., Ltd), filled in simulation fracture temporarily stifled
Agent carries out performance evaluation to diverting agent.Core model is fill out sand tube: diameter 5cm, length 20cm.Experimental temperature is set as 50 DEG C.
With simulated formation salt water to be lower than 1cm3The flow velocity displacement rock core of/min collects discharge liquor with balance.Fill out sand tube lower layer is 20-40
The diverting agent b of mesh pressure break Lanzhou quartz sand, diverting agent a and the 20g thickness of upper layer 100g thickness is filled up, diverting agent with a thickness of
11mm is fitted into pressure core flow tester after screwing, and is slowly injected into simulated formation salt water, and experimental result is as shown in Figure 1.Pass through reality
Testing can see, and when diverting agent a and diverting agent b sequence are added, and mass ratio is 5: 1, the plugging strength of Complex Temporary Blocking agent can
Up to 40MPa, when being even up to 45MPa in the case where test equipment allows, and stopping injection, pressure is remained unchanged.
Comparative example 1
It is corresponding with embodiment 1, save diverting agent b partially hydrolyzed polyacrylamide (PHPA) particle conduct, and only Jin Shiyong with it is compound
Soluble acrylate's resin of 1 identical weight of diverting agent obtains comparison diverting agent 1 as rigid diverting agent a.
The plugging strength of measurement comparison diverting agent 1 under the conditions of in the same manner as in Example 1, the injection pressure of test process with
Time variation diagram is as shown in Figure 2.It being found in test, comparison diverting agent 1 can not block simulation fracture completely, liquid exudation is had,
By huge discharge can only increase pressure break, and once stop injection liquid, rapid pressure drop.
Comparative example 2
It is corresponding with embodiment 1, Soluble acrylate's resin is saved as diverting agent a, and only Jin Shiyong and Complex Temporary Blocking agent 1
The partially hydrolyzed polyacrylamide (PHPA) of identical weight obtains comparison diverting agent 2 as intumescent diverting agent b.
The plugging strength of measurement comparison diverting agent 2 under the conditions of in the same manner as in Example 1.Test discovery, compares diverting agent 2
Pressure can not be formed.
Comparative example 3
In the experiment using core flow test instrument, by embodiment 1 diverting agent a and diverting agent b be pre-mixed
Mixture is added in fill out sand tube, is measured its plugging strength under the same conditions as example 1, is as a result seen Fig. 3.Experiment hair
Existing, the maximum pressure for comparing diverting agent can only achieve 30MPa, small compared with embodiment 1, and can only continue for some time.
Comparative example 4
The experimentation of comparative example 3 is repeated, keeps filler overall thickness constant, but increases the usage ratio of diverting agent a, is made
The weight ratio for obtaining diverting agent a and diverting agent b is 10: 1, and experimental result is shown in Fig. 4.It can be seen from the figure that final plugging effect
It slightly improves, but although final pressure reaches 40MPa, but pressure can not continue, after injecting stopping, rapid pressure drop.
It by embodiment 1 and the result of comparative example 3-4 as it can be seen that under same amount, uses, produces after diverting agent a and b are mixed
Raw plugging effect is poorer than effect used according to the invention；In this case, need to greatly increase the dosage ability of diverting agent a
Slightly improve plugging effect.After possible two kinds of diverting agents mixing, diverting agent b is easy the stream with liquid due to its flexibility characteristics
Dynamic to occur to consider mistake, once pressure is more than certain value, just forming current by pass declines pressure.In addition, for diverting agent, such as
The plugging strength of Complex Temporary Blocking agent described in embodiment 1 can reach 40MPa or more, illustrate that in practical applications, this is compound
Diverting agent has had quite outstanding temporary stifled performance.
Embodiment 2
With granule of polyvinyl alcohol (Shanghai Kai Du International Trading Company Ltd) for diverting agent a, is crushed, screen out 5-10
Purpose particle；It, will with the copolymer (Shandong Dong Da polymer Co., Ltd) of carboxymethyl cellulose and acrylamide for diverting agent b
It is crushed, and screens out the particle of 10-20 mesh；Diverting agent a and b constitutes Complex Temporary Blocking agent 2.
Into the water by diverting agent a and diverting agent b, diverting agent a expands very little in 2h, and diverting agent b expands about 5 times.
It is put into down in 80 DEG C of water containing 2wt% ammonium persulfate after diverting agent a and diverting agent b is mixed with weight ratio 6: 1,
Dissolution rate reaches 95% or more.The water insoluble matter content of mixture that measurement diverting agent a and diverting agent b weight ratio are 6: 1 is
4.0wt%.
Using rock core fluidity test instrument, the seal-off effect of evaluating combined diverting agent 2 under the same conditions as example 1
Can, only the present embodiment is 6: 1 using the weight ratio of diverting agent a and diverting agent b, diverting agent with a thickness of 10mm.Test discovery,
The plugging strength of Complex Temporary Blocking agent 2 is up to 40MPa, and after injection stops, pressure is remained unchanged, and pressure keeps curve similar and implementation
Example 1.
Embodiment 3
With sulfonated gilsonite (Shandong Province Yanggu dragon's fountain chemical plant) for diverting agent a, is crushed, screen out 4-10 purpose
Grain；With carboxymethyl cellulose (Changzhou City Guoyu Environmental Science & Technology Co., Ltd.) for diverting agent b, is crushed, screen out 10-20 mesh
Particle；Diverting agent a and b constitutes Complex Temporary Blocking agent 3.
Into the water by diverting agent a and diverting agent b, diverting agent a hardly expands in 2h, and diverting agent b expands about 4 times.
It is put at 60 DEG C in the water containing 3%HCl after diverting agent a and diverting agent b is mixed with weight ratio 8: 1, dissolution rate
Reach 96% or more.The water insoluble matter content for the mixture that measurement diverting agent a and diverting agent b weight ratio are 8: 1 is 5.2wt%.
Using rock core fluidity test instrument, the seal-off effect of evaluating combined diverting agent 3 under the same conditions as example 1
Can, only the present embodiment is 8: 1 using the weight ratio of diverting agent a and diverting agent b, and diverting agent overall thickness is still about 10mm.Through reality
It issues after examination and approval now, the plugging strength of Complex Temporary Blocking agent 3 is up to 40MPa, and after injection stops, pressure is remained unchanged, and pressure keeps class of a curve
Like with embodiment 1.
Embodiment 4
The present embodiment is by the Complex Temporary Blocking agent of embodiment 1 in the construction of Mr. Yu's oil field fracturing.Oil field DC*-* well target zone
The master data of master data is as shown in table 1.
Table 1
The initial stage daily oil production 1.5t/d in the oil field, in November, 2010 initial stage daily output 2.6t/d after common pressure break for the first time,
The decline of later period yield is very fast, adds up 2490 tons of oil-producing, this well feed flow is very poor at present, day oil-producing 0.8t, and aqueous 3.0%.
In November, 2014 carries out refracturing to DC*-* well, and pump note program is as shown in table 2, and construction curve is shown in Fig. 5.It is first low
Discharge capacity injects active water and carries out well-flushing and set packer, later with 3.5m3The discharge capacity of/min carries out pressing crack construction；Step 3-7
It is stitched always to activate, then termination of pumping 30min；Step 7-8 be injection diverting agent, successively inject diverting agent a and diverting agent b to always stitch into
Row blocks；Step 9-10 is to press off new seam.
The pump note program list of table 2
* prepad fluid, load fluid involved in table 2, displacement fluid and specific crosslinked fluid just and linear glue can be by these
Field technical staff's conventional selection.
From construction curve Fig. 5 and its data statistics it is found that rigid diverting agent enters the stratum stage, it may expand temporarily stifled a and enter
Stratum staged pressure rises to 19.1MPa from 16.8, increases 2.3MPa；Inflatable temporarily stifled b agent enters the stratum stage, pressure from
19.1 rise to 57.9MPa, increase 38.8MPa, illustrate that the response for newly stitching generation is obvious.
Construction results: initial production is 13 times of initial stage after first common pressure break, reaches 33.8t/d.Average day oil-producing after pressure
7.01 tons, be 8.76 times of first common fracturing yield increasing.Illustrate by using Complex Temporary Blocking agent provided by the invention and temporarily stifled
After method carries out refracturing, effect of increasing production is obvious.
Although the present invention has been described in detail, it will be understood by those skilled in the art that in spirit and scope of the invention
Modification will be apparent.However, it should be understood that various aspects, different specific embodiment that the present invention records
Each section and the various features enumerated can be combined or all or part of exchange.In above-mentioned each specific embodiment, that
A little embodiments with reference to another embodiment can be combined suitably with other embodiment, this is will be by this field skill
Art personnel are to understand.In addition, it will be understood to those of skill in the art that the description of front is only exemplary mode, not purport
In the limitation present invention.
Claims (12)
1. it is a kind of for temporarily blocking up the Complex Temporary Blocking method of turnaround fracture, including the stratum for being applied to temporarily block up by Complex Temporary Blocking agent
In crack；In temporary stifled program, first diverting agent a is injected in formation fracture, then again injects diverting agent b in formation fracture；
The Complex Temporary Blocking agent includes that diverting agent a and diverting agent b, the diverting agent a are selected from rigid diverting agent, and the diverting agent b is selected from
Dilatancy diverting agent；
The weight ratio of the diverting agent a and diverting agent b is (5-10): 1；
The diverting agent a is selected from Soluble acrylate's resin, gelatin, lignosulfonate, sulfonated gilsonite, sulfonated lignite, polyethylene
One of pure and mild polyesteramide is a variety of；And/or
The diverting agent b be selected from carboxymethyl starch, partially hydrolyzed polyacrylamide (PHPA), carboxymethyl cellulose, carboxymethyl cellulose with
One of copolymer of the copolymer of acrylamide, hydroxyethyl cellulose and acrylamide is a variety of.
2. Complex Temporary Blocking method according to claim 1, which is characterized in that the weight ratio of the diverting agent a and diverting agent b
For (5-8): 1.
3. Complex Temporary Blocking method according to claim 1, which is characterized in that the diverting agent a is selected from gelatin, sulfonated gilsonite
At least one of with Soluble acrylate's resin；And/or
The diverting agent b is selected from the copolymer of partially hydrolyzed polyacrylamide (PHPA) and/or carboxymethyl cellulose and acrylamide.
4. Complex Temporary Blocking method according to claim 1, which is characterized in that the average grain of the diverting agent a and diverting agent b
Diameter ratio is (1.5-5): 1.
5. Complex Temporary Blocking method according to claim 4, which is characterized in that the average grain of the diverting agent a and diverting agent b
Diameter ratio is (2-4): 1.
6. Complex Temporary Blocking method according to claim 1, which is characterized in that the particle size of the diverting agent a is 2-20
Mesh；The particle size of the diverting agent b is 4-20 mesh.
7. Complex Temporary Blocking agent according to claim 6, which is characterized in that the particle size of the diverting agent a is 4-10 mesh；
The particle size of the diverting agent b is 6-20 mesh.
8. Complex Temporary Blocking method according to claim 1, which is characterized in that the diverting agent a is non-expansibility diverting agent,
2h inner volume expands 2-10 times to the diverting agent b in water；And/or
The water insoluble matter content of the Complex Temporary Blocking agent is 7wt% or less.
9. Complex Temporary Blocking method according to claim 1, which is characterized in that the dosage of the Complex Temporary Blocking agent is to make crack
The temporarily blocking layer of middle formation with a thickness of 8-15mm.
10. Complex Temporary Blocking method according to claim 9, which is characterized in that the dosage of the Complex Temporary Blocking agent is to make to split
The temporarily blocking layer formed in seam with a thickness of 9-12mm.
11. according to claim 1, Complex Temporary Blocking method described in any one of 9 and 10, which is characterized in that the Complex Temporary Blocking
Temporarily stifled turnaround fracture and sealing temporarily block up turnaround fracture method in stitching.
12. Complex Temporary Blocking method described in any one of -11 is in old well refracturing, unconventional reservoir body according to claim 1
Overstock the application split, in the transformation of straight well separate stratum fracfturing, horizontal well fracturing and complex situations well.
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