CN107237618A - A kind of method of bottom water sandstone reservoirs volume increase control water - Google Patents
A kind of method of bottom water sandstone reservoirs volume increase control water Download PDFInfo
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- 229910002651 NO3 Inorganic materials 0.000 claims description 3
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- 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
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Abstract
The present invention relates to oil-gas reservoir hydraulic fracturing renovation technique field, relate more specifically to a kind of method for increasing production control water suitable for bottom water sandstone reservoirs.It comprises the following steps：Step A：The characterisitic parameter of longitudinal profile of geostress and intrinsic fracture is assessed；Step B：The governing factor for making seam height and bearing height is analyzed；Step one：Reservoir, the excessively extension of the high longitudinal direction of the initial seam of control are pre-processed using acid solution；Step 2：Waterproof is realized using RPM fracturing fluids as the Pad fluid injection stratum of pressure break；Step 3 five：Variable element combination fracturing technology, the proppant progress for carrying different-grain diameter and density using different viscosity liquids becomes discharge capacity construction, control critical eigenvalue extension extension and reasonable effective laying of proppant；Step 6：The proppant in pit shaft is replaced at the sealing of crack completely using the low slime body such as low-viscosity slippery water；Step 7：If construction midsole water water layer is pressed off, terminate in pressing crack construction and after crack closure, take voltage limiting mode to inject in crack the RPM fracturing fluids after exacerbation, waterborne altered with hinder in bottom aqueous layer.
Description
Technical field
The present invention relates to oil-gas reservoir hydraulic fracturing renovation technique field, relate more specifically to a kind of method suitable for bottom water sandstone reservoirs fracturing yield increasing and effective control water.
Background technology
Tight sand bottomwater gas field reservoir is generally poor due to physical property condition, and most of gas wells must could obtain industrial production capacity by fracturing reform, and fracture technology has become one of such reservoir stimulation and the core technology of effective exploitation.Tight sand bottomwater gas field reservoir is due to nearer from bottom aqueous layer, and being easy to link up water layer during fracturing reform causes water yield after pressure to be significantly increased, and water-blocking effect is serious, constrains the throughput of gas.The fracturing reform of such current reservoir is mainly the problem of the control method for making seam height and bearing height has different degrees of, causes final volume increase control water effect not good, is in particular in the following aspects：
1) FRACTURING DESIGN and scope of construction item are generally bigger than normal, cause the seam height in crack excessively to extend downwardly in the vertical；
2) pressing crack construction discharge capacity is bigger than normal, bottom pressure is easily caused quickly to collect coalescence rise, cause to stitch high extension too fast, too high, especially when the stress difference of pressure break purpose reservoir and interlayer up and down is unbalanced, too high discharge capacity can cause seam height faster to extend to the small vertical direction of stress difference；
3) design of fracturing fluid viscosity and application are not reasonable, and most of pressing crack construction whole process all use single fracturing liquid system or a kind of viscosity fracturing fluid system, and the viscosity of fracturing fluid is generally higher, cause and stitch high excessive extension；
4) proppant optimization is preferably inadequate, and the proppant type used in construction is relatively simple, and density is of a relatively high, once meet high out of control and press channeling water layer, proppant can be caused too high in the fracture condudtiviy of water layer inner support, water transmitting ability is excessive, aggravate water-blocking effect.
To solve the problems that tight sand bottomwater gas field reservoir fracturing faces, effective transformation to such reservoir is realized, it is necessary to propose a kind of method for improving fracturing reform validity the water sandstone reservoirs fracturing process bottom of suitable on the basis of effective waterproof, control water.
The content of the invention
The present invention proposes to improve the method and technique of fracturing reform validity a kind of water sandstone reservoirs fracturing process bottom of suitable on the basis of effective waterproof, control water.The method of bottom water sandstone reservoirs volume increase control water proposed by the present invention, follow the technical thought for first preventing controlling afterwards, pass through profile of geostress explication de texte, make seam height and the Analysis The Main Control Factor of bearing height, use new Relative Permeability Modifier (Relative Permeability Modifier, RPM) fracturing fluid and variable element combination fracturing technology, avoid pressing off water layer to greatest extent, improve " validity " of such reservoir fracturing, realize the target that gas production volume increase is reached on the water base plinth of anti-water control, improve the fracturing transformation effect and reservoir development degree of such reservoir.
Therefore, the invention provides a kind of method of bottom water sandstone reservoirs volume increase control water, it comprises the following steps：
Step one：Reservoir is pre-processed using acid solution.
Step 2：Stratum is injected using RPM fracturing fluids as the Pad fluid of pressure break.
Step 3：Pressing crack construction is carried out using the first fracturing fluid of the proppant for carrying 70/140 mesh, wherein, in the pressing crack construction, the discharge capacity of first fracturing fluid is 2.0-3.0m3/ min, first fracturing fluid is low glutinous fracturing fluid (for example can be slippery water and/or the linear glue not being crosslinked), the viscosity of first fracturing fluid is in below 20mPa.s, and the bulk density of the first fracturing fluid of the proppant for carrying 70/140 mesh is 1.5-1.8g/cm3；For example, in general, the viscosity of first fracturing fluid is in below 10mPa.s；If reservoir intrinsic fracture is relatively developed, it can suitably increase liquid viscosity according to leak-off experiment and fracturing fracture analog result, such as viscosity is 10-20mPa.s.
Step 4：Pressing crack construction is carried out using the second fracturing fluid of the proppant for carrying 40/70 mesh, wherein, in the pressing crack construction, the discharge capacity of second fracturing fluid is 3.0-4.0m3/ min, second fracturing fluid sticks fracturing fluid (can be for example fracturing fluid base fluid and/or the fracturing fluid of weak crosslinking) in being, the viscosity of second fracturing fluid is 30-60mPa.s, and the bulk density of the second fracturing fluid of the proppant for carrying 40/70 mesh is 1.25-1.5g/cm3；Wherein, the viscosity of second fracturing fluid liquid viscosity can be adjusted according to fracturing technology requirement.
Step 5：Pressing crack construction is carried out using the 3rd fracturing fluid of the proppant for carrying 30/50 mesh, wherein, in the pressing crack construction, the discharge capacity of the 3rd fracturing fluid is 4.0-6.0m3/ min, the 3rd fracturing fluid is high glutinous fracturing fluid (for example can be crosslinked fracturing fluid), and the viscosity of the 3rd fracturing fluid is in 120-150mPa.s, and the bulk density of the 3rd fracturing fluid of the proppant of the mesh of carrying 30/50 is 1.05-1.25g/cm3.Wherein, the requirement that the discharge capacity of the 3rd fracturing fluid can add proppant according to fracturing technology requirement and high sand ratio stage in later stage optimizes adjustment to liquid viscosity.
Step 6：The proppant in pit shaft is replaced at the sealing of crack completely using thinlyfluids such as low-viscosity slippery water, the viscosity of the low-viscosity (mobile) liquid is in below 10mPa.s, and the consumption of the thinlyfluid is hole volume and surface line volume sum.
Step 7：If because construction wrong or other factors cause bottom water water layer to be pressed off in construction, then to terminate in pressing crack construction and after crack closure, it will aggravate in RPM fracturing fluids injection crack, and well head pressure of injection pressure when being less than crack closure, waterborne be altered with hinder in bottom aqueous layer.
Wherein, when variable element combination fracturing technology is constructed, low discharge capacity, low-viscosity fracturing fluid can effectively control to make the initial extension of seam height；By variable density, the cooperation of change particle diameter proppant, the proppant of high density small particle is deposited in seam bottom control seam relative superiority or inferiority and altered；The high viscosity fracturing fluid and low-density propping agent in later stage coordinate, and major control proppant is supported in the middle and upper part of reservoir, prevent most proppants to be all deposited to seam bottom and cause aqueous significantly rising.
In a detailed embodiment, methods described is additionally included in step A and B before step one, wherein, step A：The characterisitic parameter of longitudinal profile of geostress and intrinsic fracture is assessed；Step B：The governing factor for making seam height and bearing height is analyzed.
In a detailed embodiment, the characterisitic parameter of longitudinal profile of geostress and intrinsic fracture includes lithology, physical property, rock mechanics, longitudinal profile of geostress and intrinsic fracture development characteristics etc., and the purpose is to be that fracturing technology and liquid optimization design provide comprehensive and accurate basic data.
In a detailed embodiment, the seam height and the governing factor of bearing height made includes uncontrollable geologic parameter and controllable fracturing parameter, and preferably described uncontrollable geologic parameter includes poor longitudinal direction storage barrier stress, the difference of longitudinal direction storage interlayer Young's modulus and fracture toughness etc.；It is preferred that the controllable fracturing parameter includes the first fracturing fluid, the second fracturing fluid and the respective injection discharge capacity of the 3rd fracturing fluid, viscosity and injected slurry volume, type, addition and the construction of proppant add sand concentration of sand etc..
In a detailed embodiment, single factor test sensitivity analysis is carried out to uncontrollable geologic parameter and the controllable fracturing parameter using results of fracture simulation software, wherein, preferably described results of fracture simulation software is selected from least one of commercialization results of fracture simulation software such as FracPro, StimPlan and GOHFER.
Wherein, uncontrollable geologic parameter can be controlled by the fine well and story selecting before pressure.
Generally, the viscosity and discharge capacity of fracturing fluid are of a relatively high to the influence degree for making seam height, and the parameter such as sand concentration (sand liquor ratio) of proppant density, particle diameter and construction plus sand influences larger to bearing height；In addition, in order to prevent from pressing off bottom aqueous layer, the selection for perforated interval should try one's best away from bottom aqueous layer.
In a detailed embodiment, in the step one, the acid solution and injection parameter are selected according to the condition of the reservoir；It is preferred that the condition of the reservoir includes the mineral constituent of the reservoir；It is preferred that the acid solution includes hydrochloric acid and/or mud acid；It is preferred that the injection parameter includes the consumption of the acid solution, the discharge capacity of more preferably described acid solution is 0.5-1.3m3/min.As in general, the discharge capacity of the acid solution can be 0.5-1.0m3/min；But in the intrinsic fracture comparative development of reservoir, acid solution discharge capacity can suitably increase 20-30% or so, such as the discharge capacity of described acid solution can be 1.0-1.3m3/min。
The selection of acid solution will consider the ore deposit feature of abundant reservoir, can be optimized acid formula with conventional hydrochloric acid or mud acid for acid-sensitive reservoir, be prevented acid-sensitive.Acid solution consumption can require comprehensive according to fracturing fracture simulation and specific well conditions and fracturing technology and determine.
In a detailed embodiment, the pre- preposition fracturing fluids of RPM in the step 2 are Relative Permeability Modifier fracturing fluid；It is preferred that the consumption of the Relative Permeability Modifier fracturing fluid is determined based on the analog result for being commercialized results of fracture simulation software such as FracPro, StimPlan and GOHFER, more preferably described RPM Pad fluids make seam length and to reach that the results of fracture simulation Software for Design always makes more than the 60% of seam length.
Wherein, Relative Permeability Modifier (Relative Permeability Modifier, RPM) fracturing fluid that characteristic is mutually oozed in change is a kind of liquid system for being similar to and organically combining fracturing technique and water-plugging technique；When the fracturing liquid runs into water, fluid molecule diastole blocks water stream channel；When the fracturing liquid runs into gas or oil, fluid molecule shrinks, and the ponding to oil gas almost can be ignored.
In pressing crack construction, RPM fracturing fluids are regard as Pad fluid；During pressure break makes seam, RPM fracturing fluids are percolated always in crack leading edge in the certain distance of sides of fracture vertical direction, and realizing near sides of fracture plays the role of RPM fracturing fluids, finally reach that control water increases the purpose of gas during the row of returning and operation after pressure.
RPM fracturing fluid action periods and RPM fracturing fluids diafiltration depth in the earth formation and holdup time length are related, and RPM fracturing fluids filtrate diafiltration depth is bigger, the holdup time is longer, and it controls water, and to increase gas effect better.
The consumption of Relative Permeability Modifier fracturing fluid, typically requires that Pad fluid makes seam length and is at least up to results of fracture simulation Software for Design always makes seam length more than 60%；If pressure break target zone intrinsic fracture comparative development, it can take and a certain proportion of thickener is added in RPM or adds solid drop filtering agent such as a little powder potteries etc. to drop filter measure in construction.
Therefore, in a detailed embodiment, the engineering time in the step 3, to make the 60-70% that seam height reaches the total height of expected design, makes the 20-30% that seam length reaches expected design.
Step 3: the engineering time in four and five per stage is commercialized the analog result of results of fracture simulation software to determine based on FracPro, StimPlan and GOHFER etc.；As described above, the engineering time of step 3 with make seam height reach expected design total height 60-70%, make seam length reach results of fracture simulation Software for Design expected from 70-80% be defined；After step 3 terminates, it is considered to which pressing crack construction is difficult to degree, if making seam narrow width plus sand is difficult, it can suitably increase the engineering time of step 4, otherwise, can moderately increase the engineering time of final step five.
If because construction wrong or other factors cause water layer to be pressed off in construction, to carry out pressing off the work of the control water harnessing after water layer；Specific practice can be：Pressing crack construction terminates after crack closure, RPM fracturing fluids will be aggravated to take in the measure injection crack that pressure limiting (well head pressure when injection pressure is less than crack closure) does not limit discharge capacity, discharge capacity strictly is controlled in injection process, prevents the crack closed from opening again and causes a large amount of proppants to sink.
It is larger due to aggravating RPM fracturing fluid density, it is substantially at the bottom section in crack behind injection crack, therefore after pressure in fracturing fluid recovery (backflow) and production process, as long as rationally controlling producing pressure differential, fracturing fluid can substantially be trapped in Slit bottom for a long time, hinder the waterborne of bottom aqueous layer to alter.
In addition, the injected slurry volume for aggravating RPM fracturing fluids can be by volumetric balance principle design, below gas-bearing formation bottom 2.0-3.0m is calculated until the crevice volume of the Slit bottom of water layer, and injected by the amount of 1.0-1.1 times of crevice volume, to reach purpose that the crevice volume that may link up water layer is covered as far as possible.Therefore, in a detailed embodiment, the injected slurry volume of the exacerbation RPM fracturing fluids is below gas-bearing formation bottom 2.0-3.0m until 1.0-1.1 times of crack cumulative volume of the Slit bottom of water layer.
In a detailed embodiment, bromide and/or nitrate are contained in the exacerbation RPM fracturing fluids.Bromide therein and/or nitrate are customary amount.
The method and technology of bottom water sandstone reservoirs control water volume increase proposed by the invention, thinking are succinct, and scene is easy to operation to implement；According to said method carry out the design and construction of the Fracturing Project of bottom water sand rock Gas Reservoir, can effectively solve tight sand bottomwater gas field reservoir pressure break during fracturing reform make seam height control that " effective " support of not good, Fracture System is difficult, water-blocking effect is protruded, after pressure water yield be significantly increased, press after increase production control water effect it is undesirable in terms of the problem of；On the basis of realizing that control water increases gas target, the effective flow conductivity of fracture support efficiency and crack in reservoir is improved to greatest extent, the fracturing transformation effect and reservoir development degree of such reservoir are improved to greatest extent.
Of the present invention and method and technique thinking are successfully applied in the Fracturing Project optimization design of domestic multiple bottom water sandstone reservoirs blocks and experiment, through field test application, this method adaptability and with strong points, tool operability are proved, field test application effect is good.
Embodiment
With reference to embodiment, the invention will be further described, but protection scope of the present invention is not limited to following embodiments.
The various liquid used in the present invention, such as acid solution, RPM fracturing fluids, low viscosity fracturing fluid, middle viscosity fracturing fluid, high viscosity fracturing fluid and low viscosity slippery water can be obtained from various commercial sources.
Embodiment 1
The present embodiment is purchased from petroleum works Institute for Research and Technology of Sinopec Group using RPM fracturing fluids, low viscosity fracturing fluid, middle viscosity fracturing fluid, high viscosity fracturing fluid and low viscosity slippery water.
X wells be positioned at sinopec gas field one mouth containing bottom water straight well sandstone reservoirs, interval of interest lithology be grey packsand containing gravel, pressure break well section be 2857.7-2868.5m, 10.8m/1 layers, pressure break target zone lower section 7.3m at there is bottom water；Target zone core test average pore 9.3%, mean permeability 3.5mD belongs to low hole ultra-permeable reservior；Target zone pressure coefficient is 1.07, and 106 DEG C of formation temperature belongs to normal temperature and pressure gas reservoir.Situation, this well target zone minimum principal stress average 44.1MPa, target zone top interlayer minimum principal stress number average 49.7MPa, bottom interlayer minimum principal stress average 47.2MPa are explained according to stress profile.
In order to evaluate the gas-bearing property and its production capacity of target zone sand group, and carry out lower step exploration assessment work to the block, using process proposed by the present invention, with reference to this well actual conditions, the design of hydraulic fracturing scheme and site pilot test of the well are carried out, specific implementation method and effect are as follows：
(1) liquid system is preferred：Predicting reservoir temperature is 106 DEG C or so, the preferably fracturing fluid system of 110 DEG C of heatproof.
1. slippery water formula：0.10% drag reducer SRFR-2,0.3% clay stabilizer SRCS-2,0.1% cleanup additive SRCA-2, surplus clear water；Apparent viscosity is in 1.1-2.0mPas, density 0.99-1.02g/cm3(25 DEG C), pH value 6.5-7.5, drag reducing efficiency 65-70%.
2. low-viscosity pressure break formula of liquid：0.2%SRFP-1 thickeners, 0.3%SRCS-1 expansion-resisting agents, 0.1%SRCU-1 cleanup additive liquid；Viscosity：10-20mP·s；PH value：6-7.
3. middle viscosity pressure break formula of liquid：0.35%SRFP-1 thickeners, 0.3%SRCS-1 expansion-resisting agents, 0.1%SRCU-1 cleanup additives；Liquid viscosity：30-40mP·s；PH value：6-7.
4. high viscosity pressure break formula of liquid：0.55%SRFP-1 thickeners, 0.2%SRFC-1 crosslinking agents, 0.3%SRCS-1 expansion-resisting agents, 0.1%SRCU-1 cleanup additives；Liquid viscosity：110-120mP·s；PH value：6-7.
(2) acid solution pretreatment stage：With 1.0m3/ min discharge capacities squeeze into 10m3With reservoir compatibility preferably preposition mud acid.
(3) with 2.0m3/ min discharge capacities inject 150m3RPM fracturing fluids.
(4) with 2.5m3/ min discharge capacities inject 302m3Low-viscosity fracturing fluid, and the ceramsite propping agent of 70/140 mesh is added with slug formula sand injection manner in injection process, slug formula adds sand, compared with step sand ratio, the proppant 14.5m that mode (2%-4%-6%-8%-10%) adds 70/140 mesh altogether to be increased with ladder with 3% sand3。
(5) with 3.5-4.0m3/ min discharge capacities inject 182m3Middle viscosity fracturing fluid, and the ceramsite propping agent of 40/70 mesh is added with slug formula sand injection manner in injection process, slug formula adds sand, compared with step sand ratio, to add the proppant 14.4m of 40/70 mesh altogether in the increased mode of ladder (12%-14%-16%-18%) with 6% sand3。
(6) with 4.5-5.5m3/ min discharge capacities inject 240m3High viscosity fracturing fluid, and the ceramsite propping agent of 30/50 mesh is added with slug formula+continous way (continous way is used after 24% sand ratio) sand injection manner in injection process, slug formula adds in sand with 8% sand compared with step sand ratio, and mode (18%-20%-22%) plus sand are increased with ladder；Continous way adds sand, compared with step, to add sand, most high sand ratio 32% using 2% sand ratio as step with 24% sand；The proppant 37.5m of 40/70 mesh is added altogether3。
(7) stage is replaced：With 5.5m3/ min discharge capacities are pumped into 14.0m3Slippery water is balanced replacement, and replacement terminates rear termination of pumping pressure measurement and dropped 2 hours, then terminates the well construction.
Pressure break pilot test is carried out to the test well and some mouthfuls of test block well by above-mentioned steps, site construction technology is successful, is proved by the pilot test of several mouthfuls of wells in the area：Using process proposed by the present invention, by Well-temperature after pressure and results of fracture simulation interpretive analysis, crack fracture height control is good in pressing crack construction, and crack, which is concentrated mainly in Reservoir Fracture, to be extended, and does not occur stitching high out-of-control condition；Pressure break site construction technology is successful, and construction success rate is high；From the point of view of mining after pressure and pilot production situation, non-output stratum water after pressure；Tolerance at initial stage day is obtained after good volume increase stable yields effect, pressure after the production capacity statistical analysis after pressure, several mouthfuls of area test well pressure and averagely reaches 40000m3Tolerance is stable in 25000-30000m day after/d, stable yields3/ d, is that adjacent wells using conventional fracturing technology implements after 2-4 times or so of well production, pressure that primiparity is apparently higher than offset well, production decline speed is also considerably slower than offset well, and the term of validity rises appreciably, and achieves and significantly increases production stable yields effect, improves the fracturing transformation effect of such reservoir.
Claims (10)
1. a kind of method of bottom water sandstone reservoirs volume increase control water, it comprises the following steps：
Step one：Reservoir is pre-processed using acid solution；
Step 2：Stratum is injected using RPM fracturing fluids as the Pad fluid of pressure break；
Step 3：Pressing crack construction is carried out using the first fracturing fluid of the proppant for carrying 70/140 mesh, wherein, in the pressure break
During construction, the discharge capacity of first fracturing fluid is 2.0-3.0m3/ min, first fracturing fluid is low glutinous fracturing fluid, described the
The viscosity of one fracturing fluid is in below 20mPa.s, and the bulk density of the first fracturing fluid of the proppant for carrying 70/140 mesh is
1.5-1.8g/cm3；It is preferred that the low glutinous fracturing fluid is slippery water and/or the linear glue not being crosslinked；
Step 4：Pressing crack construction is carried out using the second fracturing fluid of the proppant for carrying 40/70 mesh, wherein, applied in the pressure break
In man-hour, the discharge capacity of second fracturing fluid is 3.0-4.0m3/ min, second fracturing fluid sticks fracturing fluid, described second in being
The viscosity of fracturing fluid is 30-60mPa.s, and the bulk density of the second fracturing fluid of the proppant for carrying 40/70 mesh is
1.25-1.5g/cm3；It is preferred that it is fracturing fluid base fluid and/or the fracturing fluid of weak crosslinking that fracturing fluid is sticked in described；
Step 5：Pressing crack construction is carried out using the 3rd fracturing fluid of the proppant for carrying 30/50 mesh, wherein, applied in the pressure break
In man-hour, the discharge capacity of the 3rd fracturing fluid is 4.0-6.0m3/ min, the 3rd fracturing fluid is high glutinous fracturing fluid, the described 3rd
The viscosity of fracturing fluid is in 120-150mPa.s, the bulk density of the 3rd fracturing fluid of the proppant of the mesh of carrying 30/50
1.05-1.25g/cm3；It is preferred that the high glutinous fracturing fluid crosslinked fracturing fluid；
Step 6：The proppant in pit shaft is replaced at the sealing of crack completely using thinlyfluid, the low-viscosity (mobile) liquid
Viscosity in below 10mPa.s, the consumption of the thinlyfluid is hole volume and surface line volume sum；It is preferred that described
Thinlyfluid is low viscosity slippery water；
Step 7：If bottom water water layer is pressed off, terminate in pressing crack construction and after crack closure, RPM fracturing fluids will be aggravated
Inject in crack, and well head pressure of injection pressure when being less than crack closure, waterborne altered with hinder in bottom aqueous layer.
2. according to the method described in claim 1, it is characterised in that methods described is additionally included in the step A before step one
And B, wherein,
Step A：The characterisitic parameter of longitudinal profile of geostress and intrinsic fracture is assessed；
Step B：The governing factor for making seam height and bearing height is analyzed.
3. method according to claim 2, it is characterised in that longitudinal profile of geostress and the characteristic of intrinsic fracture
Parameter includes lithology, physical property, rock mechanics, longitudinal profile of geostress and intrinsic fracture development characteristics.
4. according to the method in claim 2 or 3, it is characterised in that described to make seam height and the governing factor of bearing height
Including uncontrollable geologic parameter and controllable fracturing parameter, preferably described uncontrollable geologic parameter include longitudinal direction storage every
Ply stress is poor, the difference and fracture toughness of longitudinal direction storage interlayer Young's modulus；It is preferred that the controllable fracturing parameter is including described
First fracturing fluid, second fracturing fluid and the respective injection discharge capacity of the 3rd fracturing fluid, viscosity and injected slurry volume, support
Type, addition and the construction of agent add the sand concentration of sand.
5. the method according to any one in claim 2-4, it is characterised in that using results of fracture simulation software to described
Uncontrollable geologic parameter and the controllable fracturing parameter carry out single factor test sensitivity analysis, wherein, it is preferably described to split
Stitch simulation softward and be selected from least one of FracPro, StimPlan and GOHFER results of fracture simulation software.
6. the method according to any one in claim 1-5, it is characterised in that in the step one, according to institute
The condition for stating reservoir selects the acid solution and injection parameter；It is preferred that the condition of the reservoir includes the mineral constituent of the reservoir；
It is preferred that the acid solution includes hydrochloric acid and/or mud acid；It is preferred that the injection parameter includes the consumption of the acid solution, more preferably described acid
The discharge capacity of liquid is 0.5-1.3m3/min。
7. the method according to any one in claim 1-6, it is characterised in that before RPM in the step 2 is pre-
Fracturing fluid is put for Relative Permeability Modifier fracturing fluid；It is preferred that the consumption of the Relative Permeability Modifier fracturing fluid is based on crack
The analog result of simulation softward is determined；More preferably described RPM Pad fluids make that seam length reaches FRACTURING DESIGN always make seam
More than the 60% of length.
8. the method according to any one in claim 1-7, it is characterised in that described Step 3: in four and five
Engineering time determined based on the analog result of results of fracture simulation software.
9. the method according to any one in claim 1-8, it is characterised in that contain in the exacerbation RPM fracturing fluids
There are bromide and/or nitrate.
10. the method according to any one in claim 1-9, it is characterised in that the note of the exacerbation RPM fracturing fluids
Enter volume for below gas-bearing formation bottom 2.0-3.0m until 1.0-1.1 times of the crevice volume amount of the Slit bottom of water layer.
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