CN106917619A - Temporary plugging steering and fracture supporting integrated transformation method for fractured carbonate reservoir - Google Patents
Temporary plugging steering and fracture supporting integrated transformation method for fractured carbonate reservoir Download PDFInfo
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- CN106917619A CN106917619A CN201710170058.4A CN201710170058A CN106917619A CN 106917619 A CN106917619 A CN 106917619A CN 201710170058 A CN201710170058 A CN 201710170058A CN 106917619 A CN106917619 A CN 106917619A
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- fracturing fluid
- stratum
- fluid
- temporary blocking
- gelled fracturing
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- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 21
- 238000011426 transformation method Methods 0.000 title abstract 2
- 239000012530 fluid Substances 0.000 claims abstract description 123
- 239000002253 acid Substances 0.000 claims abstract description 52
- 238000000034 method Methods 0.000 claims abstract description 47
- 239000007924 injection Substances 0.000 claims abstract description 37
- 238000002347 injection Methods 0.000 claims abstract description 37
- 239000011435 rock Substances 0.000 claims abstract description 23
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 21
- 230000010354 integration Effects 0.000 claims abstract description 15
- 239000007788 liquid Substances 0.000 claims abstract description 15
- 230000000903 blocking effect Effects 0.000 claims description 51
- 239000003795 chemical substances by application Substances 0.000 claims description 30
- 238000007789 sealing Methods 0.000 claims description 28
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 28
- 238000001802 infusion Methods 0.000 claims description 25
- 239000000835 fiber Substances 0.000 claims description 22
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 19
- 239000002981 blocking agent Substances 0.000 claims description 18
- 230000009466 transformation Effects 0.000 claims description 17
- 239000010410 layer Substances 0.000 claims description 16
- 239000002245 particle Substances 0.000 claims description 13
- 150000007513 acids Chemical class 0.000 claims description 11
- 238000006073 displacement reaction Methods 0.000 claims description 10
- 239000011229 interlayer Substances 0.000 claims description 10
- 238000007634 remodeling Methods 0.000 claims description 7
- 125000002057 carboxymethyl group Chemical group [H]OC(=O)C([H])([H])[*] 0.000 claims description 6
- 239000003292 glue Substances 0.000 claims description 5
- 238000004088 simulation Methods 0.000 claims description 5
- 230000008859 change Effects 0.000 claims description 4
- 239000001913 cellulose Substances 0.000 claims description 2
- 229920002678 cellulose Polymers 0.000 claims description 2
- 238000003825 pressing Methods 0.000 claims description 2
- 230000002269 spontaneous effect Effects 0.000 claims description 2
- 239000011159 matrix material Substances 0.000 claims 1
- 239000004576 sand Substances 0.000 abstract description 4
- 239000002131 composite material Substances 0.000 abstract 4
- 238000005086 pumping Methods 0.000 abstract 2
- 230000004048 modification Effects 0.000 abstract 1
- 238000012986 modification Methods 0.000 abstract 1
- 239000002994 raw material Substances 0.000 description 13
- 239000000203 mixture Substances 0.000 description 11
- 239000000243 solution Substances 0.000 description 10
- 238000005260 corrosion Methods 0.000 description 9
- 230000007797 corrosion Effects 0.000 description 9
- 230000000694 effects Effects 0.000 description 8
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 6
- 239000000654 additive Substances 0.000 description 6
- 230000000996 additive effect Effects 0.000 description 6
- 238000010276 construction Methods 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 6
- 230000005764 inhibitory process Effects 0.000 description 5
- 229920000642 polymer Polymers 0.000 description 5
- 229920002907 Guar gum Polymers 0.000 description 3
- 239000000665 guar gum Substances 0.000 description 3
- 229960002154 guar gum Drugs 0.000 description 3
- 235000010417 guar gum Nutrition 0.000 description 3
- 229910052742 iron Inorganic materials 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 239000002562 thickening agent Substances 0.000 description 3
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 description 2
- 230000000844 anti-bacterial effect Effects 0.000 description 2
- 239000003899 bactericide agent Substances 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 238000004891 communication Methods 0.000 description 2
- 238000004132 cross linking Methods 0.000 description 2
- 239000003431 cross linking reagent Substances 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 230000036632 reaction speed Effects 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 239000003381 stabilizer Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 244000241257 Cucumis melo Species 0.000 description 1
- 235000015510 Cucumis melo subsp melo Nutrition 0.000 description 1
- 235000019738 Limestone Nutrition 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- -1 carboxymethyl melon Chemical compound 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000003978 infusion fluid Substances 0.000 description 1
- 235000015110 jellies Nutrition 0.000 description 1
- 239000008274 jelly Substances 0.000 description 1
- 239000006028 limestone Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000009418 renovation Methods 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 239000002195 soluble material Substances 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 230000001131 transforming effect Effects 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/261—Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation
-
- 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
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)
- Sealing Material Composition (AREA)
Abstract
The invention provides a temporary plugging steering and fracture supporting integrated transformation method for a fractured carbonate reservoir. Wherein, when the stratum needing to be modified is 1 layer, the stratum comprises: step A1, injecting a pad fluid and an in-seam composite temporary plugging system into a formation pump; step B1, pumping acid with viscosity-changing capability into the stratum; c1, injecting sand-carrying liquid and displacing liquid into the formation pump to complete the reconstruction; when the rock formation to be modified is more than 2 layers, the method comprises the following steps: step A2, injecting a pad fluid and an in-seam composite temporary plugging system into a formation pump; step B2, pumping acid with viscosity-changing capability into the stratum; step C2, injecting a gel fracturing fluid and a displacing fluid containing the fracture composite temporary plugging system into the stratum pump; and (4) repeating the operations from the step A2 to the step C2 according to the number of layers to be modified, wherein when the last pump injection is carried out, the gel fracturing fluid containing the seam composite temporary plugging system is not injected, but the sand carrying fluid is injected, so that the modification is completed. The method can realize the integration and synchronization of temporary plugging steering and fracture supporting.
Description
Technical field
The present invention relates to a kind of temporary stall of slit formation carbonate reservoir to fracture support integration remodeling method, belong to
Well production increment renovation technique field.
Background technology
Implement acidfracturing treatment because acid-rock reaction speed is fast for high temperature, deep layer, slit formation carbonate reservoir, acid solution has
Effect operating distance is short, and fracture tip is difficult to provide effective flow conductivity, and crack arrival end is connect for a long time due to acid solution with crack
Touch, acid solution causes near-wellbore region acid corrosion fracture retentivity poor (He Chunming, Guo Jian to rock mechanics strength failure
Spring,《The Mechanism Study that acid solution influences on limestone mechanical property》, Chinese Journal of Rock Mechanics and Engineering, 2013 (s2)：3016-3021),
Influence the effect of acidfracturing treatment.Raising transformation volume is needed to realize that crack is laterally and vertical simultaneously for slit formation carbonate reservoir
Correctional effect could be further improved to turning to, temporarily stifled in most effective seam at present is exactly the temporarily stifled such as TSOP fracturing of fracture tip, and
The temporarily stifled closure for being difficult to whole fracture height in other regions in seam, is only capable of playing a part of to improve net pressure in seam, and
Sealing is temporarily stifled because the big closure difficulty of fracture aperture is big, simple particle diverting agent can disperse in injection process (Yang Zhao is medium,
A kind of multistage temporarily stifled depth network acid fracturing method, CN106194145), it is difficult to it is optimal plugging effect.
Therefore it provides a kind of temporary stall of slit formation carbonate reservoir turns into this to fracture support integration remodeling method
Field technical problem urgently to be resolved hurrily.
The content of the invention
In order to solve the above technical problems, it is an object of the invention to provide a kind of temporary stall of slit formation carbonate reservoir to
With fracture support integration remodeling method, the method can make full use of temporarily stifled steering procedure to realize fracture support, by temporary stall
To with fracture support integration, synchronize, improve slit formation carbonate reservoir acidfracturing treatment effect.
To reach above-mentioned purpose, the invention provides a kind of temporary stall of slit formation carbonate reservoir to fracture support one
Body remodeling method, wherein,
When the number of plies for needing the rock stratum of transformation is 1 layer, the method is comprised the following steps：
Step A1, to Complex Temporary Blocking system in stratum infusion prepad fluid and seam；
Step B1, the acid to stratum infusion with the ability that becomes sticky, to form man-made fracture, while away from shaft area reality
The temporary of existing crack tip is blocked up；
Step C1, to stratum infusion load fluid and displacement fluid, complete the temporary stall of slit formation carbonate reservoir to and crack
Support the transformation of integration；
When the number of plies for needing the rock stratum of transformation is more than 2 layers, the method is comprised the following steps：
Step A2, to Complex Temporary Blocking system in stratum infusion prepad fluid and seam, to form man-made fracture, while away from well
Realize the temporarily stifled of crack tip in cylinder region；
Step B2, the acid to stratum infusion with the ability that becomes sticky；
Step C2, the gelled fracturing fluid and displacement fluid of sealing Complex Temporary Blocking system is contained to stratum infusion, to realize crack
The temporary of sealing is blocked up；
The number of plies transformed as needed, the operation of repeat step A2 to step C2, wherein, carrying out last time infusion
When, the gelled fracturing fluid containing sealing Complex Temporary Blocking system is not injected into, but load fluid is injected, complete the storage of slit formation carbonate rock
The temporary stall of layer is to the transformation with fracture support integration.
In the technical scheme that the present invention is provided, the number of plies transformed as needed, repeat step A2 is to step C2's
Operation.Wherein, in last time infusion, the gelled fracturing fluid containing sealing Complex Temporary Blocking system is not injected into, but injection is taken
Sand liquid is primarily referred to as：When needing the number of plies of transformation more than 2 layers, most start and each layer of centre all carries out step A2 to step
The operation of rapid C2, when transforming last layer, carries out step A2 to after the operation of step B2, and sand is taken to stratum infusion
Liquid and displacement fluid.For example when the number of plies for needing transformation is 2 layers, the operation of step A2 to step C2 is carried out to ground floor, it is then right
The second layer carries out the operation of step A2 to step B2, then to stratum infusion load fluid and displacement fluid；The number of plies for needing transformation is 3
During layer, the operation of step A2 to step C2 is carried out respectively to ground floor and the second layer, step A2 to step is then carried out to third layer
The operation of rapid B2, then to stratum infusion load fluid and displacement fluid.
The present invention has found when fracture type carbonate reservoir carries out temporarily stifled research：Temporarily stifled key area is to split in seam
The end of seam and the arrival end in crack, and the impacted key area of flow conductivity is also end and the entrance in crack in crack
End.The technical scheme that the present invention is provided can make full use of temporarily stifled steering procedure to realize fracture support, by temporary stall to and crack
Support integration, synchronization, further improve the acidfracturing treatment effect of slit formation carbonate reservoir.
Complex Temporary Blocking system can also be referred to as to stitch interior Complex Temporary Blocking in seam described in the technical scheme of present invention offer
Agent, the sealing Complex Temporary Blocking system can also be referred to as sealing Complex Temporary Blocking agent.
In the above-mentioned methods, it is preferable that before being transformed, the method is further comprising the steps of：
The rock mechanics parameters data of the rock stratum for needing transformation are obtained, the rock mechanics parameters data include Young's modulus
Data and Poisson's ratio data；
Based on the rock mechanics parameters data for obtaining, simulated by FracPT acid fracturings optimizing Design Software and obtain preposition liquid pump
Note terminates the aperture of rear fracture tip, and when replacing stage injection interlayer diverting agent crack arrival end aperture；
Terminate crack arrival end when aperture, the replacement stage injection interlayer diverting agent of rear fracture tip according to prepad fluid infusion
Aperture, and different opening crack temporarily stifled selection plate, it is determined that Complex Temporary Blocking system and sealing Complex Temporary Blocking system in seam.
In the above-mentioned methods, the aperture of crack arrival end is primarily referred to as in main pressure break during replacement stage injection interlayer diverting agent
After injection stage terminates, when being transferred to the replacement stage, it is necessary to reduce injection discharge capacity (will main pressure break injection stage injection discharge capacity by
The injection discharge capacity of a certain fixation is gradually reduced to, wherein, the injection discharge capacity of main pressure break injection stage and the injection discharge capacity of a certain fixation
As needed temporarily depending on the crack of stifled transformation) to interlayer diverting agent is injected in crack, drop discharge capacity injects the process of interlayer diverting agent
In can be calculated the aperture of crack arrival end.
In the above-mentioned methods, the temporarily stifled selection plate in the different opening crack is set up by Logistics automatic system.Plate
Abscissa be the volume and the ratio between the volume (equivalent to sand ratio) for carrying liquid of solid phase particles (Degradable temporary blocking agent+proppant),
Unit is m3/m3；Ordinate is the volume of biodegradable fiber and carries the ratio between volume of liquid.In the technical scheme that the present invention is provided
In, diverting agent is added in gelled fracturing fluid.
In the above-mentioned methods, it is preferable that the prepad fluid includes slippery water and/or gelled fracturing fluid；During injection prepad fluid,
Slippery water is first injected, gelled fracturing fluid is injected afterwards；The ratio of the slippery water and the gelled fracturing fluid can be according to reservoir
Actual temperature and leak-off situation are adjusted, it is highly preferred that the volume ratio of the slippery water and the gelled fracturing fluid is (1:
1)-(3:1)；It is further preferred that the gelled fracturing fluid is acid-resistant pressing crack liquid, it includes acid carboxymethyl fracturing fluid, spontaneous
One or more in acid fracturing fluid and acid cross-linked cellulose fracturing fluid.
In the technical scheme that the present invention is provided, the raw material of the slippery water is constituted and matches what can be transformed as needed
The actual conditions of rock stratum are adjusted, it is preferable that by percentage to the quality, and the raw material composition of the slippery water includes：0.1% carboxylic
Methyl guar gum, 0.5% cleanup additive, 0.2% clay stabilizer, balance of water.
In the technical scheme that the present invention is provided, the raw material composition and proportioning of the gelled fracturing fluid can change as needed
The actual conditions of the rock stratum made are adjusted, it is preferable that by percentage to the quality, the raw material composition bag of the gelled fracturing fluid
Include：0.5% carboxymethyl guar gum, 0.2% viscous steady agent, 0.5% cleanup additive, 0.2% crosslinking accelerator, 0.05% bactericide, surplus
It is water.
In the above-mentioned methods, it is preferable that in injection seam during Complex Temporary Blocking system, Complex Temporary Blocking system is added and frozen in first stitching
In fracturing fluid, in then reinjecting stratum；It is highly preferred that Complex Temporary Blocking system includes biodegradable fiber, can drop in the seam
Solution diverting agent and proppant；It is further preferred that when Complex Temporary Blocking system adds gelled fracturing fluid in stitching, biodegradable fiber
Volume is 0.2-0.3% with the volume ratio of gelled fracturing fluid, and the volume of Degradable temporary blocking agent is with the volume ratio of gelled fracturing fluid
2-4%, the volume of proppant is 3-10%, more preferably 5-10% with the volume ratio of gelled fracturing fluid.
In the above-mentioned methods, it is preferable that include during Complex Temporary Blocking system in stratum injection prepad fluid and seam：
Slippery water and gelled fracturing fluid are prepared, the gelled fracturing fluid is divided into three parts, Part I is pure frozen glue pressure
Liquid is split, Part II is the gelled fracturing fluid that with the addition of proppant, and Part III is the jelly that with the addition of Complex Temporary Blocking system in seam
Fracturing fluid；
Slippery water is injected to stratum；
The gelled fracturing fluid that be implanted sequentially pure gelled fracturing fluid to stratum, with the addition of proppant and with the addition of be combined in seam temporary
The gelled fracturing fluid of stifled system；Wherein, in the gelled fracturing fluid that with the addition of proppant, volume and the frozen glue pressure of proppant
The volume ratio for splitting liquid can be 3%-5%.
In the above-mentioned methods, the pure gelled fracturing fluid, with the addition of the gelled fracturing fluid of proppant and with the addition of multiple in seam
The volume ratio for closing temporarily stifled this three part of the gelled fracturing fluid of system can be adjusted according to difficulty of construction, difficulty of construction more it is big then
The ratio of pure gelled fracturing fluid is higher, and difficulty of construction is more low, with the addition of the ratio of the gelled fracturing fluid of Complex Temporary Blocking system in seam
It is higher, it is preferable that the pure gelled fracturing fluid, to the addition of the gelled fracturing fluid of proppant and with the addition of Complex Temporary Blocking system in seam
This three part of gelled fracturing fluid volume ratio be (1:1:1)-(3:1:1).Under some construction environments
In the above-mentioned methods, in the seam aperture in the crack that the size of Complex Temporary Blocking system can be blocked as needed and
It is fixed, the size=2-2.5 of the aperture/particle in usual crack；Preferably, the length of the biodegradable fiber is 4-6mm；It is described can
The particle diameter of degraded diverting agent is 30-70 mesh；The particle diameter of the proppant is 70-140 mesh.
In the above-mentioned methods, it is preferable that the sealing Complex Temporary Blocking system include biodegradable fiber, Degradable temporary blocking agent and
Proppant；It is highly preferred that when the gelled fracturing fluid containing sealing Complex Temporary Blocking system is prepared, the volume of biodegradable fiber
It is 1-1.8% with the volume ratio of gelled fracturing fluid, the volume of Degradable temporary blocking agent is 4-10% with the volume ratio of gelled fracturing fluid,
More preferably 4-6%, the volume of the proppant is 10-15% with the volume ratio of gelled fracturing fluid.The sealing Complex Temporary Blocking
Depending on the aperture in the crack that the size of system can be blocked as needed, the size=1-1.5 of the aperture/particle in usual crack,
It is further preferred that the length of the biodegradable fiber is 6-9mm, the particle diameter 6-20 mesh of the Degradable temporary blocking agent, the branch
The particle diameter for supportting agent is 30-140 mesh, more preferably 30-70 mesh.
In the above-mentioned methods, it is preferable that the biodegradable fiber and Degradable temporary blocking agent can be by water-soluble or acid-soluble
Material is prepared；The biodegradable fiber and Degradable temporary blocking agent can degrade under the conditions of 60-150 DEG C by 4-10h.
In the above-mentioned methods, it is preferable that infusion, the construction of the oil pipe and sleeve pipe are carried out to stratum using oil pipe or sleeve pipe
Discharge capacity is 8-10m3/min；It is highly preferred that a diameter of 4in or 4-1/2in of the oil pipe, a diameter of 5in of described sleeve pipe or
5-1/2in, the oil pipe and sleeve pipe limited using the present invention disclosure satisfy that operational discharge capacity 8-10m3The infusion requirement of/min.
In the above-mentioned methods, it is preferable that the acid with the ability of becoming sticky includes VES self-diverting acids, pH containing hydrochloric acid
Value control polymer becomes the combination of one or more that glactaric acid and temperature control become in glactaric acid；It is highly preferred that the VES containing hydrochloric acid
The mass percent concentration of hydrochloric acid is 15-20% in self-diverting acid.
In the technical scheme that the present invention is provided, the raw material composition and proportioning of the VES self-diverting acids containing hydrochloric acid can
It is adjusted with the actual conditions of the rock stratum transformed as needed, it is preferable that by weight percentage, it is described containing hydrochloric acid
The raw material composition of VES self-diverting acids includes：15%HCl, 3-5%VES, 4.5% corrosion inhibiter, the steady agent of 2% iron, 0.15% inhibition promote
Enter agent, balance of water.
In the technical scheme that the present invention is provided, the raw material composition that the pH value control polymer becomes glactaric acid can generally be wrapped
PH value control is included to become sticky polymer thickening agent, corrosion inhibiter, ferrous stability, cleanup additive, crosslinking agent and water；The temperature control becomes glactaric acid
Raw material composition can generally be become sticky polymer thickening agent, corrosion inhibiter, ferrous stability, cleanup additive, crosslinking agent including temperature control
And water；Those skilled in the art can become the raw material group of glactaric acid and temperature control change glactaric acid according to actual conditions to pH value control polymer
It is adjusted into proportioning.
In the above-mentioned methods, it is preferable that wherein, the gelled fracturing fluid containing sealing Complex Temporary Blocking system is injected to stratum
When, it is 1-2m to control injection discharge capacity3/ min, to reduce the aperture in crack, improves the closure probability of sealing.
In the technical scheme that the present invention is provided, proppant in the load fluid is haydite, but not limited to this.
Beneficial effects of the present invention：
(1) in the seam selected by/temporarily stifled system is the mixed of biodegradable fiber, Degradable temporary blocking agent and ceramsite propping agent to sealing
Close sample.The system is both including the flexible material such as fiber and diverting agent, and including rigid ceramsite propping agent, and more existing flexibility is temporarily stifled
System plugging strength is high, and the automatic recovery ability that system is temporarily blocked up compared with rigidity is stronger, can further improve temporarily stifled turning efficiency；This
Outward, in stitching/temporarily stifled system is turned to after interlayer steering sealing in completion seam, biodegradable fiber and Degradable temporary blocking agent can be molten
Solution, leaves proppant fracture end and crack arrival end is supported, and improves acid corrosion fracture and flow conductivity
Retentivity；
(2) technical scheme that the present invention is provided can make full use of temporarily stifled steering procedure to realize fracture support, by temporary stall
To with fracture support integration, synchronize, further improve slit formation carbonate reservoir acidfracturing treatment effect.
Brief description of the drawings
Fig. 1 is that the schematic diagram turned to interlayer is turned in seam；
Fig. 2 is fracture aperture distribution map along its length；
Fig. 3 is the temporarily stifled selection plate in different opening crack；
Fig. 4 is the construction curve of embodiment well acidfracturing treatment.
Specific embodiment
In order to be more clearly understood to technical characteristic of the invention, purpose and beneficial effect, now to skill of the invention
Art scheme carry out it is described further below, but it is not intended that to it is of the invention can practical range restriction.
Embodiment
Present embodiments provide a kind of temporary stall of slit formation carbonate reservoir to fracture support integration remodeling method.
The present embodiment (as shown in Figure 1) with North China Oilfield well as research object, the well buried depth reaches 5400m, reservoir temperature
Degree reaches 177 DEG C, develops multiple dimensioned intrinsic fracture, belongs to deeper clefts type carbonate rock hydrocarbon reservoir.
The method that the present embodiment is provided is comprised the following steps：
Step 1, according to the reservoir rock mechanics parameter that indoor core experiment and well-log information are calculated, major parameter bag
Young's modulus is included for 30000-50000MPa, Poisson's ratio is 0.15-025；
Infusion program according to design obtains prepad fluid infusion and terminates rear crack using the simulation of FracPT acid fracturing designs software
The aperture of end check is that the aperture of crack arrival end during 1mm or so, and injection interlayer diverting agent is 5mm or so, such as
Shown in Fig. 2.
Step 2, the aperture and the aperture of crack arrival end of the fracture tip obtained according to step 1 simulation, while using thing
Temporarily stifled selection plate (i.e. the preferred plate of diverting material) in the different opening crack that mould experiment is set up, it is determined that Complex Temporary Blocking body in seam
System and sealing Complex Temporary Blocking system (as shown in Figure 3).
The aperture of the fracture tip obtained using the simulation of FracPT acid fracturing designs software is 1mm, therefore, it is multiple in optimal seam
Closing temporarily stifled system includes：1. Degradable temporary blocking agent, its particle diameter is 0.4mm or so (30 mesh), the body of its volume and gelled fracturing fluid
Product is than being 3%；2. ceramsite propping agent, its size is 70-140 mesh, and its volume is 7% with the volume ratio of gelled fracturing fluid；3. may be used
Degradation of fibers, its length is 6mm, and its volume is 0.25% with the volume ratio of gelled fracturing fluid；0.25% biodegradable fiber+
The 70-140 mesh ceramsite propping agents of 3% 30 mesh Degradable temporary blocking agents+7% constitute Complex Temporary Blocking system in seam.
The aperture of the crack arrival end that simulation is obtained is 5mm, therefore, optimal sealing Complex Temporary Blocking system includes：1. may be used
Degraded diverting agent, its size is 1.5-2mm or so (10 mesh), and its volume is 10% with the volume ratio of gelled fracturing fluid；2. haydite
Proppant, its size is 40-140 mesh, and its volume is 15% with the volume ratio of gelled fracturing fluid；3. biodegradable fiber, its size
It is 9mm, its volume is 1.2% with the volume ratio of gelled fracturing fluid；10 mesh Degradable temporaries of 1.2% biodegradable fiber+10%
The 40-140 mesh ceramsite propping agents of blocking agent+15% constitute sealing Complex Temporary Blocking system.
Step 3, in order to meet the requirement of high flow rate operation, the tubing string that this well is injected using 4-1/2in oil pipe+5in sleeve pipes
Structure, the operational discharge capacity that disclosure satisfy that can reach 10m3/min。
This well reservoir temperature is 177 DEG C, in order to realize that reservoir is lowered the temperature, while more intrinsic fractures are activated, preposition
The liquid stage injects 400m3Slippery water, by percentage to the quality, the raw material composition of the slippery water includes：0.1% carboxymethyl melon
Glue, 0.5% cleanup additive, 0.2% clay stabilizer, balance of water；The injection discharge capacity of slippery water is 8-9m3/ min, in prepad fluid
Slippery water is 1.5 with the volume ratio of gelled fracturing fluid:1.
Gelled fracturing fluid uses acid carboxymethyl fracturing fluid, by percentage to the quality, the acid carboxymethyl pressure break
The raw material composition of liquid includes：0.5% carboxymethyl guar gum, 0.2% glue steady agent, 0.5% cleanup additive, 0.2% crosslinking accelerator,
0.05% bactericide, balance of water；The gelled fracturing fluid can be effectively improved makes seam efficiency.
Because the Young's modulus of this well is higher, fracture aperture is narrower, therefore can be relative in prepad fluid injection process
The injection stage of Complex Temporary Blocking system in seam is reduced, asking for plug at end part occurs in order to avoid crack occur and not extend intoing design length
Topic, in injection seam during Complex Temporary Blocking system, load fluid is configured to during Complex Temporary Blocking system in seam is added into pure gelled fracturing fluid, is controlled
It is 3 that pure gelled fracturing fluid is made with the volume ratio of load fluid:1, and control injection discharge capacity up to 11m3/min。
Step 4, the acid solution that this well is used is mainly the VES self-diverting acids of cleaning, in order to realize making slit and realize day
The purpose that right crack is linked up, optimizes two sets of acid solutions of different thickener concentrations：
Low viscous VES self-diverting acids：By weight percentage, its raw material composition includes 15%HCl, 3%VES, 4.5% inhibition
Agent, the steady agent of 2% iron, 0.15% corrosion inhibition accelerator, balance of water, the viscosity of the low viscous VES self-diverting acids is 10mPas or so,
Corrosion communication can be carried out to intrinsic fracture, promotes contribution of the intrinsic fracture to yield；
The viscous VES self-diverting acids of height：By weight percentage, its raw material composition includes 15%HCl, 5%VES, 4.5% inhibition
Agent, the steady agent of 2% iron, 0.15% corrosion inhibition accelerator, balance of water, the viscosity of the viscous VES self-diverting acids of the height is 50mPas or so,
Acid-rock reaction speed can be reduced, corrosion communication is carried out to deep reservoir；
It is 10m that injection discharge capacity is controlled during injection acid solution3/ min, to improve the net pressure in seam, improves effective work of acid solution
With distance, the time of injection is reduced.
Step 5,15-20m is injected after terminating to individual layer transformation3Displacement fluid, displacement fluid is fracturing fluid base fluid or slippery water；
The gelled fracturing fluid containing sealing Complex Temporary Blocking system is injected after displacement fluid injection terminates, injection contains sealing Complex Temporary Blocking body
, it is necessary to discharge capacity from 8-10m will be injected during the gelled fracturing fluid of system3/ min is reduced to 1-2m3/ min, to reduce fracture aperture, improves
The closure probability of sealing.
Step 6, it is 2 layers that this well needs the interval of transformation, therefore, carry out Complex Temporary Blocking in 2 seams and turned to and 1 sealing
Complex Temporary Blocking is turned to, such as Fig. 4.
This well accumulation injection liquid measure reaches 3096m3, wherein, slippery water is 570m3, gelled fracturing fluid is 1076m3, it is low viscous
VES self-diverting acids are 600m3, the viscous VES self-diverting acids of height are 850m3.Operational discharge capacity is 8-11m3, operation pressure is up to
92MPa.16mm oil nozzles seek product after this well pressure, and well head pressure is 20MPa, and daily output tolerance is 40.9 × 104m3, daily oil production is
71m3, realize high yield.The day of 7mm oil nozzles pilot production more than 40, well head pressure remains at more than 23MPa, and daily output tolerance is 11 ×
104m3More than, daily oil production is 40m3, it is 1437m to tire out oil production3, it is 600 × 10 to tire out gas production4m3More than, tentatively realize steady
The target of product.
In sum, the technical scheme that the present invention is provided can make full use of temporarily stifled steering procedure to realize fracture support, will
Temporary stall to fracture support integration, synchronize, effectively improve the acidfracturing treatment effect of slit formation carbonate reservoir.
Claims (9)
1. a kind of temporary stall of slit formation carbonate reservoir to fracture support integration remodeling method, wherein,
When the number of plies for needing the rock stratum of transformation is 1 layer, the method is comprised the following steps：
Step A1, to Complex Temporary Blocking system in stratum infusion prepad fluid and seam；
Step B1, the acid to stratum infusion with the ability that becomes sticky；
Step C1, to stratum infusion load fluid and displacement fluid, complete the temporary stall of slit formation carbonate reservoir to and fracture support
The transformation of integration；
When the number of plies for needing the rock stratum of transformation is more than 2 layers, the method is comprised the following steps：
Step A2, to Complex Temporary Blocking system in stratum infusion prepad fluid and seam；
Step B2, the acid to stratum infusion with the ability that becomes sticky；
Step C2, the gelled fracturing fluid and displacement fluid of sealing Complex Temporary Blocking system are contained to stratum infusion；
The number of plies transformed as needed, the operation of repeat step A2 to step C2, wherein, when last time infusion is carried out, no
Gelled fracturing fluid of the injection containing sealing Complex Temporary Blocking system, but injection load fluid, complete slit formation carbonate reservoir temporary
Stall is to the transformation with fracture support integration.
2. method according to claim 1, wherein, before being transformed, the method is further comprising the steps of：
The rock mechanics parameters data of the rock stratum for needing transformation are obtained, the rock mechanics parameters data include Young's modulus data
With Poisson's ratio data；
Based on the rock mechanics parameters data for obtaining, simulation obtains the aperture that prepad fluid infusion terminates rear fracture tip, Yi Jiding
The aperture of crack arrival end when injecting interlayer diverting agent for the stage；
Crack arrival end opens when terminating aperture, the replacement stage injection interlayer diverting agent of rear fracture tip according to prepad fluid infusion
Degree, and the temporarily stifled of different opening crack selects plate, it is determined that Complex Temporary Blocking system and sealing Complex Temporary Blocking system in seam.
3. method according to claim 1, wherein, the prepad fluid includes slippery water and/or gelled fracturing fluid；
Preferably, when prepad fluid is injected, slippery water is first injected, gelled fracturing fluid is injected afterwards；
It is highly preferred that the volume ratio of the slippery water and the gelled fracturing fluid is (1:1)-(3:1)；
It is further preferred that the gelled fracturing fluid is acid-resistant pressing crack liquid, it includes acid carboxymethyl fracturing fluid, spontaneous matrix acidizing
One or more in liquid and acid cross-linked cellulose fracturing fluid.
4. the method according to claim any one of 1-3, wherein, in injection seam during Complex Temporary Blocking system, first will be in seam
Complex Temporary Blocking system is added in gelled fracturing fluid, in then reinjecting stratum；
Preferably, Complex Temporary Blocking system includes biodegradable fiber, Degradable temporary blocking agent and proppant in the seam；The proppant
Preferably haydite；
It is highly preferred that when Complex Temporary Blocking system adds gelled fracturing fluid in stitching, the volume and gelled fracturing fluid of biodegradable fiber
Volume ratio be 0.2-0.3%, the volume of Degradable temporary blocking agent and the volume ratio of gelled fracturing fluid are 2-4%, the body of proppant
Product is 3-10% with the volume ratio of gelled fracturing fluid；
It is further preferred that the length of the biodegradable fiber is 4-6mm；The particle diameter of the Degradable temporary blocking agent is 30-70 mesh；
The particle diameter of the proppant is 70-140 mesh.
5. the method according to claim any one of 1-4, wherein, to Complex Temporary Blocking system in stratum injection prepad fluid and seam
When include：
Slippery water and gelled fracturing fluid are prepared, the gelled fracturing fluid are divided into three parts, Part I is pure gelled fracturing fluid,
Part II is the gelled fracturing fluid that with the addition of proppant, and Part III is the frozen glue pressure break that with the addition of Complex Temporary Blocking system in seam
Liquid；
Slippery water is injected to stratum；
To the pure gelled fracturing fluid of stratum injection, with the addition of the gelled fracturing fluid of proppant and with the addition of Complex Temporary Blocking system in seam
Gelled fracturing fluid.
6. method according to claim 1, wherein, the sealing Complex Temporary Blocking system includes biodegradable fiber, degradable
Diverting agent and proppant；The proppant is preferably haydite；
Preferably, when the gelled fracturing fluid containing sealing Complex Temporary Blocking system is prepared, the volume of biodegradable fiber with freeze
The volume ratio of fracturing fluid is 1-1.8%, and the volume of Degradable temporary blocking agent is 4-10% with the volume ratio of gelled fracturing fluid, described
The volume of proppant is 10-15% with the volume ratio of gelled fracturing fluid；
It is highly preferred that the length of the biodegradable fiber is 6-9mm, the particle diameter of the Degradable temporary blocking agent is 6-20 mesh, described
The particle diameter of proppant is 30-140 mesh.
7. method according to claim 1, wherein, infusion, the oil pipe and set are carried out to stratum using oil pipe or sleeve pipe
The operational discharge capacity of pipe is 8-10m3/min。
8. method according to claim 1, wherein, the acid with the ability of becoming sticky includes the VES rotations containing hydrochloric acid
To one or more in acid, pH value control change glactaric acid and temperature control change glactaric acid；
Preferably, in the VES self-diverting acids containing hydrochloric acid, the mass percent concentration of hydrochloric acid is 15-20%.
9. method according to claim 1, wherein, the gelled fracturing fluid of sealing Complex Temporary Blocking system is contained to stratum infusion
When, it is 1-2m to control injection discharge capacity3/min。
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