CN107558979A - A kind of method of shale volume pressure break - Google Patents
A kind of method of shale volume pressure break Download PDFInfo
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- CN107558979A CN107558979A CN201610511590.3A CN201610511590A CN107558979A CN 107558979 A CN107558979 A CN 107558979A CN 201610511590 A CN201610511590 A CN 201610511590A CN 107558979 A CN107558979 A CN 107558979A
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Abstract
A kind of method of shale volume pressure break, the present invention relates to shale volume fracturing technique field.Constructed by pad stage using the change discharge capacity of long period, and coordinate multiple closing well termination of pumping, minimize crustal stress anisotropy to the greatest extent, to realize the abundant extension of the steering of major fracture extension path and different scale Fracture System especially smaller scale fine fisssure slot sytem.After many cracks appearance, infusion relatively full-bodied fracturing fluid when playing pump again, high discharge capacity is coordinated to inject, and suitably increase the ratio of low-viscosity slippery water and the ratio of 70 140 mesh proppants, to further expand previous established fine fisssure slot sytem and realize the filling to various small yardstick fine fisssure slot sytems as far as possible with small particle proppant, subsequently sand pump note program is added to complete infusion construction according to the master of design.
Description
Technical field
The present invention relates to shale volume fracturing technique field.
Background technology
Different from the fracturing technology of routine, volume fracturing is in hydraulic fracturing process, forms a major fracture or a plurality of
Intrinsic fracture is linked up while major fracture, and brittle rock is produced the destructions such as bad break, shearing, sliding, formation is naturally split
Seam and the interlaced fracture network of man-made fracture, reach the purpose for expanding transformation volume, improving Reservoir Seepage passage.With page
The popularization and application of the unconventionaloil pool reservoir volume fracturing technique such as rock gas, industry have formd a common recognition is how to be applied existing
Under the conditions of work, hydraulically created fracture complexity degree and overall " effective " transformation volume are improved to greatest extent.
At present on volume fracturing implementing process be then by more shower holes fracture parameters carry out integral layout optimization, this
It is the strategic act for improving crack transformation volume, including stitches long, flow conductivity and seam (cluster) spacing optimization etc.；It is basic herein
On, every cluster fracture initiation is controlled with extension, such as becomes viscosity fracturing fluid, the combination of more particle diameter proppants plus sand and different viscositys
Fracturing fluid alterative injection technology etc., to improve the complexity degree singly stitched to greatest extent.The combination of above-mentioned two technology, with regard to structure
Into current so-called " effective " volume fracturing technology.
But because the Forming Mechanism in shale volume crack is complicated and the randomness feature of shale geologic parameter distribution itself, very
It is relatively fewer that the probability in so-called volume crack can just be formed, if Fuling Jiao's masonry dam is considered as that most successful shale gas exploitation is shown
Model area, but assessed by diagnosis research after various pressures, the volume crack accounting really formed is only in 30% or so, also 30-
40% crack is still conventional single crack, and remaining 30-40% is the crack for having certain complexity degree.Summary is got up,
For volume fracturing technological angle, problems with is still suffered from：
1) discharge capacity lifting speed is fast, just mentions the highest discharge capacity of design in 3-5min mostly.But what high discharge capacity was formed splits
Seam face relative smooth, easily closure loses flow conductivity too early in crack after pressure.It is also easy to form single crack in addition, makes numerous small split
Gap or stratification/texture seam lose the chance linked up and extended.
2) proppant adds opportunity and mode is difficult to hold.Added including proppant concentration design, different-grain diameter proppant
Time, injection way etc., once it is improper to design unreasonable or constructing operation, easily cause in seam sand fallout and situations such as sand plug.
3) shale pressure break generally takes disposable injection to complete at present, and the judgement to fracture pattern and extension feature brings tired
Difficulty, makes the real-time adjustment of construction parameter have random and uncertainty.In addition, the induced stress in crack is not made full use of
Effect, makes crack complexity degree be difficult to further be lifted.
The content of the invention
Invention provides a kind of process suitable for shale gas reservoir volume fracturing reform, solves different shale physical property bars
Fluid efficiency under the influence of part, rock mechanics condition, crustal stress anisotropy and line/stratification difference development characteristics etc. is low, makes
Stitch the technological difficulties such as effect is poor, crack complexity is not high, transformation finite volume.By the implementation of present invention process, with maximum
Expected " effective " crack transformation volume and fracturing yield increasing effect are improved to limit, realizes and oil in place is employed.Pass through
Prepad fluid (such as slippery water that viscosity the is 1-3mPas) stage uses such as 3-4m3/ min is low, and discharge capacity injection viscosity is 1-
3mPas slippery water is constructed, and coordinates the multiple termination of pumping (stopping injecting for example described slippery water) of such as 2-3 times,
Prepad fluid make seam the time be 2-3 hours, minimize crustal stress anisotropy to the greatest extent, with realize major fracture extension path turn
To and different scale Fracture System especially smaller scale fine fisssure slot sytem abundant extension.After many cracks appearance, then
During secondary pump, with such as 6-8m3/ min higher displacements injection viscosity 20-25mPas glue, is replaced with same displacement afterwards
Injection prepad fluid (such as slippery water that viscosity is 1-3mPas), until after crack seam length reaches design load, proceeds by and adds sand
Pressing crack construction, appropriate in work progress to increase the dosage for taking sand low-viscosity slippery water, its usage ratio at least accounts for total load fluid
40 volume %-60 volume % of amount, and the ratio of 70-140 mesh small particle proppants is increased, its dosage accounts for the 30 of total support dosage
Volume %-40 volume %, to further expand previous established fine fisssure slot sytem and be realized as far as possible with small particle proppant
Filling to various small yardstick fine fisssure slot sytems, " one section of load fluid, one subsequently designed according to general shale gas well sand fracturing
The slug mode of section insulating liquid " sequentially adds 40-70 mesh proppant and 30-50 mesh proppants, until completing injection (generally pump
Note) construction.Whole process characteristic is shown as：Prepad fluid makes the seam stage to design a length of desired value of fracturing fracture, completes 100% and makes
The saturation of seam and microfissure fills, and takes sand injection (generally infusion) without being eager to carry out main proppant, passes through " delay " construction
Design, become discharge capacity, become the effectiveness such as viscosity, stickiness fingering, increasing the complexity and connectedness of Fracture System, ultimately form nearly well and arrive
Remote well stratum has the complicated multi-scale facture system necessarily supported, to strengthen effective transformation volume in crack, so as to realize into
One step improves the purpose of fracturing transformation effect.
Specifically, the invention provides a kind of method of shale volume pressure break, it comprises the following steps：
Before when step 1, evaluating reservoir parameter, and determining to construct according to the evaluation result to the reservoir parameter
Put viscosity, injection discharge capacity and its dosage of liquid, and the dosage of total proppant；Wherein described reservoir parameter include brittleness index,
Original crustal stress, intrinsic fracture, and stratification or texture seam developmental state, the prepad fluid include the cunning that viscosity is 1-3mPas
Slip the glue of water and/or viscosity for 20-25mPas.
Step 2：The slippery water is injected to stratum, now, the dosage of the slippery water is 2-3 times of hole volume, is completed
After injecting the slippery water, suspension of works (i.e. termination of pumping, stops injecting the slippery water in other words).
Step 3：Well head pressure fall after the step 2 suspension of works reaches current position Stress Field Distribution shape
Under state two to horizontal stress difference 80%-100% when, inject the slippery water, now, the slippery water to stratum again
Dosage is 2-3 times of hole volume, and after the injection for completing this slippery water, suspension of works (i.e. termination of pumping, stops injection in other words
The slippery water).
Optional step four：Repeat step more than three times, wherein the time for continuing construction is to observe the well after suspension of works
Mouthful pressure fall reach under the Stress Field Distribution state of current position two to horizontal stress difference 80%-100% time point.
Step 5：Pitching changes in amplitude after the suspension of works of observation of steps three or step 4 reaches more than 3-5MPa
When, the glue is injected to break through nearly well multiple cracking region to stratum, realizes the communication of Deep Fractures；The dosage of the glue is
The fracture length comprising the near wellbore zone including nearly well fracture length is broken through to reach when seam long 30%-40% is expected in each crack
Dosage, adds gel breaker simultaneously during glue injection (generally infusion), and the dosage of the gel breaker is to expire
The foot glue is made in 1 minute after seam reaches expected seam length and realizes broken glue；
Step 6：The slippery water is injected to reservoir, the use of the glue in the dosage and step 5 of the slippery water
Amount is suitable.Using its with step 5 compared with caused by the viscosity difference of high viscosity glue " stickiness fingering " effect (that is, viscosity is small
A kind of unstable interfacial phenomenon caused by the larger fluid of fluid displacement viscosity, easily cause low viscosity liquid as finger
Passed through in high viscosity fluid) carry out the further expansion seam of remote well complex fracture." suitable " therein, with the dosage of the glue
On the basis of, the slippery water is differed within 5%-20% with the glue, preferably can be understood as equal.In addition, step
The dosage of the glue in slippery water and step 5 in six is preferably 1.5-2 times of hole volume.
Step 7：It is repeated in the step 5 and six at least once, number of repetition is reached with the total seam length of final simulation to be set
Meter stitches length to determine.
Step 8：The initial sand liquor ratio that slug formula injects 70-140 mesh proppant and the slippery water is 1 volume %-2 bodies
Product % mixed liquor, and the carrying amount of the slippery water carrying 70-140 mesh proppant presses 1 volume %-2 volumes %
Sand liquor ratio staged increases to 10 volume %-14 volumes %；Slug formula injection 40-70 mesh proppant is initial with the slippery water
Sand liquor ratio is 4 volume %-6 volumes % mixed liquor, and the carrying amount of the slippery water carrying 40-70 mesh proppant is pressed
1 volume %-2 volume % sand liquor ratio stageds increase to 12 volume %-14 volume %, then the support of slug formula injection 40-70 mesh
The mixed liquor that the initial sand liquor ratio of agent and the glue is 12 volume %-14 volumes %, and the glue carries the 40-70
The carrying amount of mesh proppant increases to 20 volume %-24 volumes % by 2 volume %-3 volume % sand liquor ratio stageds；Slug formula is noted
The initial sand liquor ratio for entering 30-50 mesh proppant and the glue is 18 volume %-20 volumes % mixed liquor, and the glue
The carrying amount for carrying the 30-50 mesh proppant increases to 22 volume %-26 bodies by 2 volume %-3 volume % sand liquor ratio stageds
Product %.
Step 9：It is pumped into the glue of 0.2-0.3 times of hole volume and the cunning of 1 times of hole volume successively in order
Water is slipped, the load fluid completed in step 8 replaces.Complete after the step in the case of special, to terminate to construct.
In work progress in the present invention, selective first before step 2 as needed it can be carried out to stratum
Injection pretreatment acid solution；Then slippery water is reinjected；Or directly carry out described smooth to stratum injection in the step 2
Water.
Two under the Stress Field Distribution state of current position refer to horizontal stress difference：In hydraulic fracturing process, crack wall is appointed
Meaning a little away from well different distance in the range of, original crustal stress is by induced stress function influence, maximum after its size changes
The difference of horizontal principal stress and minimum horizontal principal stress.
In a detailed embodiment, it is described Step 2: the slippery water in step 3 and optional step four
Discharge capacity be the highest discharge capacity 1/4-1/3.
In a detailed embodiment, the discharge capacity of the glue in the step 5 is the 1/3- of the highest discharge capacity
2/3。
In a detailed embodiment, the sand fracturing operational discharge capacity in the step 8 is arranged for the highest
Amount.
In a detailed embodiment, the evaluation to the parameter of reservoir can be according to well log interpretation and indoor test result.
In a detailed embodiment, used in the step 1 in MEYER, StimPlan, GOHFER
A kind of software determines the viscosity of prepad fluid during construction, injection (generally infusion) discharge capacity and its dosage, and total support
Agent dosage.
In a detailed embodiment, the total amount of the 70-140 mesh proppant accounts for 30 bodies of total proppant dosage
Product %-40 volumes %；The total amount of the 40-70 mesh proppant accounts for 40 volume %-50 volumes % of total proppant dosage；Institute
The total amount for stating 30-50 mesh proppants accounts for 10 volume %-20 volumes % of total proppant dosage.
In a detailed embodiment, alternately injection glue and slippery water, its dosage and order are pressed in the step 7
According to isometric slippery water is reinjected after first injecting 1.5-2 times of hole volume glue, at least it is repeated 1 times, until the step 7 is total
Liquid measure reaches corresponding design crack seam length；Determine the alternately glue of injection and smooth water inventory and seam in the step 7
The one kind of the software of long relation in MEYER, StimPlan, GOHFER.
The action effect of the present invention is：
Because crack seam is long and slit width is as pressure break injects (generally infusion) time and injection (generally infusion) row
The construction parameters such as amount change in real time, corresponding induced stress also difference under each fracture length and width.Therefore can
Calculated by conventional fracture simulation software, such as MEYER, StimPlan, GOHFER, obtain net pressure change and injected with pressure break
Relation between (generally infusion) time and construction parameter.Using this variation relation, seam stage note is made by extending prepad fluid
Enter (generally infusion) time, take low discharge capacity construction and the repeatedly process meanses such as termination of pumping, different scale crack system can be realized
The abundant extension of system especially smaller scale fine fisssure slot sytem, further to improve the complexity degree in crack.The termination of pumping time with
The previous termination of pumping moment (is assumed to be t1) play rise again pump construction the moment (be assumed to be t2) corresponding to this period (t2-t1)
To determine；It is required that net pressure should exceed present level stress difference in each preceding crack of termination of pumping, pump construction moment t is played again2It is corresponding
Seam is long and slit width under the conditions of induced stress caused by the minimum principal stress direction that is calculated can just make up present level stress
Difference.Fracturing work is now carried out again, and fracture initiation and extension are carried out equivalent on the isotropic stratum of stress.By preposition
The liquid stage, the crack of crack initiation was probably splitting in any angle multiple directions repeatedly after " injection-termination of pumping-injection " circulation construction
Seam, so as to realize the complexity degree for improving crack.
After different directions many cracks occur, to prevent every crack from only complex fracture system occur in nearly shaft location,
Injection (generally infusion) relatively full-bodied fracturing fluid is needed when playing pump again, to break through the cracky restriction of nearly well.Cause
Viscosity is higher, then coordinates with high discharge capacity, and the multiple cracking system of nearly well is because of each fracture width relative narrower, it is difficult to receives high row
The high viscosity fracturing fluid of injection is measured, it is inevitable finally to be extended along an advantage fractuer direction.High viscosity fracturing fluid dosage is set
Meter, the long 1/4-1/3 for reaching desired design seam length of seam that should meet extend under the conditions of certain usage amount；In pad stage
Ensure making after seam length reaches expected and require for each crack, then be supported the addition of agent.
Add proppant injection (generally infusion) construction stage, discharge capacity is brought up to the highest discharge capacity of design, and suitably add
The dosage accounting of big low-viscosity slippery water and the ratio of 70-140 mesh proppants, it is therefore an objective to which further extension is previously established
Fine fisssure slot sytem and being realized as far as possible with small particle proppant is filled out to the full charge of various small yardstick fine fisssure slot sytems.Due to low-viscosity
The ratio of slippery water is high, then coordinates and constructed with relatively high discharge capacity, even if running into the high viscosity glue system in major fracture, due to
" stickiness fingering " effect (laboratory experiment result proves that, as long as viscosity difference reaches more than 6 times, stickiness fingering effect is clearly),
Slippery water can also pass rapidly through the location of cracks that high viscose liquid occupies.But to ensure that the small particle proppant that slippery water carries also can
Quickly migrate the crack section occupied through high viscose liquid, it is contemplated that in prepad fluid injection (generally infusion) and in the termination of pumping time,
Synchronously broken glue (can matching somebody with somebody based on each high glutinous section fracturing fluid of temperature field simulation result optimizing pad stage for all high viscosity fracturing fluids
Side and gel breaker add section).
Wherein, in the present invention, each construction is named according to injection (generally infusion) phase sequence in work progress
With working solution, and slippery water in prepad fluid or glue are all one kind of fracturing fluid system.
In the present invention, nearly well refers to the region in the half long scope of major fracture of the axial 1/8-1/6 apart from well.And distance
Well is referred to as remote well axially beyond the region of 1/8-1/6 half long scope of major fracture.
In the present invention, Deep Fractures refer in the crack of half long remote well area of the major fracture close to design.
In the present invention, that sand liquor ratio represents is the volume (m of a certain stage proppant3) with take sand fracturing fluid (such as this
Slippery water or glue in invention) volume (m3The ratio between).
Instant invention overcomes Fracture System complexity caused by existing shale fracturing technology is high, multi-scale facture system
It is difficult to obtain effectively support, the problems such as volume and flow conductivity are relatively low is transformed in crack., can be further by the implementation of the present invention
Improve shale fracturing effect, improve shale gas yield.
Brief description of the drawings
Fig. 1 is the typical fracturing section hydraulic fracture operating curve schematic diagram of the well in embodiment 1.Wherein：
1. well head pressure, 2. sand liquor ratios, 3. operational discharge capacities, 4. pad stage first time terminations of pumping, 5. pad stages
Secondary termination of pumping, 6. pad stage third time terminations of pumping, the 4th termination of pumping of 7. pad stages
Embodiment
With reference to embodiment, the invention will be further described, but protection scope of the present invention is not limited to following realities
Apply example.
Embodiment 1
The formula of slippery water：The volume %-0.3 volume % expansion-resisting agents+0.1 of 0.05 volume %-0.1 volume % drag reducers+0.2
Volume %-0.15 volumes % helps row's synergist.
The formula of glue：The volume %-0.15 volume % crosslinking agents+0.2 of 0.25 volume %-0.35 volume % thickeners+0.1
The efficient volume of expansion-resisting agent+0.1 %-0.15 volumes % of volume %-0.3 volumes % help the volume %-0.08 bodies of row's synergist+0.05
Product % gel breakers.
A wells are a bite shale gas horizontal wells for being deployed in river southwest shale gas exploratory area, well depth 4600m, the well log interpretation well
Brittleness index 0.52-0.56, indoor test Young's modulus 30.19GPa, Poisson's ratio 0.228, maximum horizontal principal stress 80.3MPa,
Minimum horizontal principal stress 69.7MPa, horizontal stress difference 10.6MPa, horizontal stress coefficient of variation 0.152.Imaging logging shows mesh
The development of layer shale have a horizontal bedding seam, part stratification seam times calcite filling, and also there are close to target zone bottom shale
The joint that spacing does not wait.Pressing crack construction, specific implementation step are carried out to the well using delay fracturing technology method provided by the invention
Rapid following (Fig. 1 is well typical case's fracturing section hydraulic fracture operating curve schematic diagram)：
(1) by commenting parameters such as the horizontal well wherein one section of target zone shale brittleness index, crustal stress, intrinsic fractures
Valency, and according to small scale fracturing test diagnostic analysis result and fracturing section hydraulic fracture operating curve analysis result, judge this well mesh
Layer shale fragility condition be preferable, horizontal low stress difference is small and intrinsic fracture is developed, the well can be applied with the inventive method
Work.Through using MEYER softwares to be simulated, it is necessary to be handled by the termination of pumping of 4 prepad fluid construction stages, determine prepad fluid most
Low-viscosity is 1-3mPas, and highest viscosity is 25-30mPas；The lowest displacement of prepad fluid is 3-4m3/ min, highest discharge capacity
For 15m3/min；Total proppant dosage is 75m3Left and right, total fracturing fluid dosage are 1850m3Left and right (glue dosage accounting therein
40 volume %)；
(2) seam, slippery water viscosity 1.5mPas, discharge capacity 3-4m preposition are made as prepad fluid progress using slippery water3/
Min, inject slippery water 141m by the stage successively3、123m3、114m3、140m3, centre respectively termination of pumping 32min, 30min, 31min,
30min, as described in Figure 14,5,6,7 four terminations of pumping；
(3) discharge capacity is promoted to 6-9m3/ min, it is pumped into the glue 58m that viscosity is 25mPas3Afterwards, with step (2) phase
Same discharge capacity continues to inject 45m3Viscosity is 1.5mPas slippery water, and the fluctuation that observation well head pressure has 5.5MPa declines, this
When according to Fracturing design software MEYER analog result show that dummy joint length in crack reaches the 320m of design, therefore enter sand fracturing
Stage；
(4) use the slippery water that viscosity is 1.5mPas to be started to walk with the volume % of sand liquor ratio 1, carry 70-140 mesh haydite branch
Support agent and carry out infusion construction, operational discharge capacity is by 9m3/ min is stepped up to 12-15m3/ min, according to " one section of load fluid, one section every
The mode of chaotropic " carries out plus sand, adds 70-140 mesh ceramsite propping agents 21m altogether3；
(5) continue to keep highest design discharge capacity 15m according to " one section of load fluid, one section of insulating liquid "3/ min, carry 40-70
Mesh ceramsite propping agent, start to walk to carry out infusion construction with the volume % of sand liquor ratio 5；This stage carries 40-70 mesh haydite branch when slippery water
After support agent sand liquor ratio is up to 12 volume %, uses the glue that viscosity is 25mPas instead and carry out sand pump note；It is total to slippery water
Add 40-70 mesh ceramsite propping agents 18.8m3；
(6) continue to keep highest design discharge capacity 15m according to " one section of load fluid, one section of insulating liquid "3/ min, it is with viscosity
25mPas glue carries 40-70 mesh ceramsite propping agents, starts to walk to carry out infusion construction, 40-70 mesh with the volume % of sand liquor ratio 13
Ceramsite propping agent sand liquor ratio is up to 20 volume %, adds 40-70 mesh ceramsite propping agents 22m altogether with glue3；
(7) highest design discharge capacity 15m is kept3/ min, the glue for being 25mPas with viscosity carry 30/50 mesh haydite and supported
Agent, start to walk to carry out infusion construction with the volume % of sand liquor ratio 17, continuance lifting sand liquor ratio, 30-50 mesh ceramsite propping agent sand liquor ratio is most
Up to stopping plus sand after 20 volume %, 30/50 mesh ceramsite propping agent 15.6m is added altogether with glue3；
(8) terminate after adding sand, keep 15m3/ min, is pumped into 15m3After viscosity is 25mPas glue, it is further continued for being pumped into
40m3Viscosity is 1.5mPas slippery water, so far, completes above to replace, terminates construction.
This section construction carries out inverse modeling by Fracturing design software MEYER and shown, prepad fluid is not taken compared to adjacent segment
Make the pressing crack construction of seam stage termination of pumping delay sand fracturing measure, net pressure is effectively improved in its crack, form compared with
Volume is transformed on a large scale, and primiparity 8 × 10 is obtained after A well pressures4m3Test yield.
The exemplary only explanation of the embodiment of the present invention, but no matter the embodiment is not formed to this under any circumstance
The restriction of invention.
Although the present invention is described with reference to embodiment, it should be appreciated by those skilled in the art
In the case of without departing from the real spirit and scope of the present invention, the various changes that can carry out.Furthermore, it is possible to this hair
Bright main body, spirit and scope are variously changed to adapt to specific situation, material, material compositions and method.All
These changes are included in the range of the claim of the present invention.
Claims (6)
1. a kind of method of shale volume pressure break, it comprises the following steps：
Prepad fluid when step 1, evaluating reservoir parameter, and determining to construct according to the evaluation result to the reservoir parameter
Viscosity, injection discharge capacity and its dosage, and the dosage of total proppant；Wherein described reservoir parameter includes brittleness index, original
Crustal stress, intrinsic fracture, and stratification or texture seam developmental state, the prepad fluid include the slippery water that viscosity is 1-3mPas
And/or the glue that viscosity is 20-25mPas；
Step 2：The slippery water is injected to stratum, now, the dosage of the slippery water is 2-3 times of hole volume, completes injection
After the slippery water, suspension of works；
Step 3：Well head pressure fall after the step 2 suspension of works reaches under the Stress Field Distribution state of current position
Two to horizontal stress difference 80%-100% when, inject the slippery water, now, the dosage of the slippery water to stratum again
For 2-3 times of hole volume, after the injection for completing this slippery water, suspension of works；
Optional step four：Repeat step more than three times, wherein the time for continuing construction is to observe the well head pressure after suspension of works
Power fall reach under the Stress Field Distribution state of current position two to horizontal stress difference 80%-100% time point；
Step 5：When the Pitching changes in amplitude of observation of steps three or the suspension of works of step 4 reaches more than 3-5MPa, to
The glue is injected to break through nearly well multiple cracking region in stratum, realizes the communication of Deep Fractures；The dosage of the glue is breakthrough
Fracture length comprising the near wellbore zone including nearly well fracture length reaches use when seam long 30%-40% is expected in each crack
Amount, adds gel breaker simultaneously in the glue injection process, and the dosage of the gel breaker is that disclosure satisfy that the glue makes seam
Reach in 1 minute after expected seam length and realize broken glue；
Step 6：The slippery water, the dosage of the slippery water and the dosage phase of the glue in step 5 are injected to reservoir
When；
Step 7：It is repeated in the step 5 and six at least once, number of repetition reaches design seam with final always seam length of simulating
Grow to determine；
Step 8：The initial sand liquor ratio that slug formula injects 70-140 mesh proppant and the slippery water is 1 volume %-2 volumes %
Mixed liquor, and the slippery water carries the carrying amount of the 70-140 mesh proppant and presses 1 volume %-2 volume % sand liquid
10 volume %-14 volumes % are increased to than staged；Slug formula injects the initial sand liquid of 40-70 mesh proppant and the slippery water
Carrying amount than the mixed liquor for 4 volume %-6 volumes %, and the slippery water carrying 40-70 mesh proppant presses 1 body
Product %-2 volume % sand liquor ratio stageds increase to 12 volume %-14 volume %, then slug formula injection 40-70 mesh proppant with
The initial sand liquor ratio of the glue is 12 volume %-14 volumes % mixed liquor, and the glue carries the 40-70 mesh branch
The carrying amount of support agent increases to 20 volume %-24 volumes % by 2 volume %-3 volume % sand liquor ratio stageds；Slug formula is injected
The mixed liquor that the initial sand liquor ratio of 30-50 mesh proppant and the glue is 18 volume %-20 volumes %, and the glue is taken
Carrying amount with the 30-50 mesh proppant increases to 22 volume %-26 bodies by 2 volume %-3 volume % sand liquor ratio stageds
Product %；
Step 9：Be pumped into successively in order 0.2-0.3 times of hole volume the glue and 1 times of hole volume it is described smooth
Water, the load fluid completed in step 8 replace.
2. according to the method for claim 1, it is characterised in that described Step 2: in step 3 and optional step four
The slippery water discharge capacity be the highest discharge capacity 1/4-1/3.
3. according to the method for claim 2, it is characterised in that the discharge capacity of the glue in the step 5 for it is described most
The 1/3-2/3 of high discharge capacity.
4. according to the method described in any one in claim 1-3, it is characterised in that the described plus sand pressure in the step 8
It is the highest discharge capacity to split operational discharge capacity.
5. according to the method described in any one in claim 1-4, it is characterised in that use is selected from the step 1
A kind of software in MEYER, StimPlan, GOHFER determines the viscosity of prepad fluid during construction, injection discharge capacity and its use
Amount, and total proppant dosage.
6. according to the method described in any one in claim 1-5, it is characterised in that the total amount of the 70-140 mesh proppant
Account for 30 volume %-40 volumes % of total proppant dosage；The total amount of the 40-70 mesh proppant accounts for total proppant and used
40 volume %-50 volumes % of amount；The total amount of the 30-50 mesh proppant accounts for 10 volume %-20 of total proppant dosage
Volume %.
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Cited By (18)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108518210A (en) * | 2018-03-29 | 2018-09-11 | 北京斯迪莱铂油气技术有限公司 | A kind of Condensate Gas Reservoir pressure break oil extraction gas production method |
| CN110029979A (en) * | 2019-05-07 | 2019-07-19 | 中国石油天然气股份有限公司 | A kind of fracturing process for realizing compact reservoir volume fracturing efficient support |
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| CN110219635A (en) * | 2018-03-01 | 2019-09-10 | 中国石油化工股份有限公司 | A kind of full size fracture support method |
| CN108518210A (en) * | 2018-03-29 | 2018-09-11 | 北京斯迪莱铂油气技术有限公司 | A kind of Condensate Gas Reservoir pressure break oil extraction gas production method |
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| CN110344799A (en) * | 2018-04-02 | 2019-10-18 | 中国石油化工股份有限公司 | A kind of critical sand plug fracturing process improving crack complexity |
| CN111140226A (en) * | 2018-11-06 | 2020-05-12 | 中国石油化工股份有限公司 | Method for improving crack flow conductivity |
| CN111140226B (en) * | 2018-11-06 | 2022-09-27 | 中国石油化工股份有限公司 | Method for improving crack flow conductivity |
| CN111911127A (en) * | 2019-05-07 | 2020-11-10 | 中国石油化工股份有限公司 | Fracturing sand adding method |
| CN111911127B (en) * | 2019-05-07 | 2022-11-25 | 中国石油化工股份有限公司 | Fracturing sand adding method |
| CN110029979A (en) * | 2019-05-07 | 2019-07-19 | 中国石油天然气股份有限公司 | A kind of fracturing process for realizing compact reservoir volume fracturing efficient support |
| CN111911128B (en) * | 2019-05-08 | 2022-11-29 | 中国石油化工股份有限公司 | High-tectonic stress normal-pressure shale gas-accumulation fracturing method |
| CN111911128A (en) * | 2019-05-08 | 2020-11-10 | 中国石油化工股份有限公司 | High-tectonic stress normal-pressure shale gas-reservoir fracturing method |
| CN110173250B (en) * | 2019-06-14 | 2021-10-15 | 北京石油化工学院 | Fracturing method for modifying dry hot rock reservoir by using nano emulsion |
| CN110173250A (en) * | 2019-06-14 | 2019-08-27 | 北京石油化工学院 | A kind of fracturing process of nanoemulsions transformation hot dry rock reservoir |
| CN112240191A (en) * | 2019-07-19 | 2021-01-19 | 中国石油化工股份有限公司 | Shale gas fracturing sand adding method |
| CN112443303A (en) * | 2019-09-04 | 2021-03-05 | 中国石油化工股份有限公司 | Method for controlling crack propagation direction |
| CN112443303B (en) * | 2019-09-04 | 2022-12-13 | 中国石油化工股份有限公司 | Method for controlling crack propagation direction |
| CN110714747A (en) * | 2019-10-21 | 2020-01-21 | 中国石油化工股份有限公司 | Three-step control method for improving shale transformation volume |
| CN113445976A (en) * | 2020-03-25 | 2021-09-28 | 中国石油化工股份有限公司 | Fracturing method and application of high-plasticity stratum |
| CN113445976B (en) * | 2020-03-25 | 2023-09-26 | 中国石油化工股份有限公司 | Fracturing method and application of high-plasticity stratum |
| CN112031733A (en) * | 2020-09-30 | 2020-12-04 | 重庆地质矿产研究院 | Fracturing method for forming and efficiently supporting complex seam network of deep shale reservoir |
| CN114458266A (en) * | 2020-10-21 | 2022-05-10 | 中国石油化工股份有限公司 | Method for improving complexity of artificial cracks for hot dry rock thermal storage transformation and application of method |
| CN114439444B (en) * | 2020-11-05 | 2024-03-01 | 中国石油天然气股份有限公司 | Reservoir fracturing method and apparatus |
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| CN112240192A (en) * | 2020-11-12 | 2021-01-19 | 中国石油天然气集团有限公司 | Fracturing method for controlling opening of shale near-well micro natural fracture |
| CN112832718A (en) * | 2021-03-12 | 2021-05-25 | 西南石油大学 | Deep shale gas development method |
| CN112832718B (en) * | 2021-03-12 | 2022-04-05 | 西南石油大学 | Deep shale gas development method |
| CN115199249A (en) * | 2021-04-13 | 2022-10-18 | 中石化石油工程技术服务有限公司 | Method for forming complex seam net by shale oil fracturing |
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