CN107989592A - A kind of horizontal well fracturing method - Google Patents
A kind of horizontal well fracturing method Download PDFInfo
- Publication number
- CN107989592A CN107989592A CN201610956610.8A CN201610956610A CN107989592A CN 107989592 A CN107989592 A CN 107989592A CN 201610956610 A CN201610956610 A CN 201610956610A CN 107989592 A CN107989592 A CN 107989592A
- Authority
- CN
- China
- Prior art keywords
- fracturing
- fluid injection
- section
- injection stage
- proppant
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 238000000034 method Methods 0.000 title claims abstract description 56
- 239000012530 fluid Substances 0.000 claims abstract description 110
- 238000002347 injection Methods 0.000 claims abstract description 59
- 239000007924 injection Substances 0.000 claims abstract description 59
- 239000004576 sand Substances 0.000 claims abstract description 55
- 239000003292 glue Substances 0.000 claims abstract description 32
- 238000003860 storage Methods 0.000 claims abstract description 12
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 64
- 238000010276 construction Methods 0.000 claims description 37
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 32
- 238000013461 design Methods 0.000 claims description 25
- 239000011435 rock Substances 0.000 claims description 19
- 239000007788 liquid Substances 0.000 claims description 16
- 239000003795 chemical substances by application Substances 0.000 claims description 14
- 238000003825 pressing Methods 0.000 claims description 14
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 claims description 13
- 239000003245 coal Substances 0.000 claims description 13
- 230000008569 process Effects 0.000 claims description 8
- 241000209094 Oryza Species 0.000 claims description 7
- 235000007164 Oryza sativa Nutrition 0.000 claims description 7
- 235000009566 rice Nutrition 0.000 claims description 7
- 235000021185 dessert Nutrition 0.000 claims description 6
- 238000009826 distribution Methods 0.000 claims description 6
- 230000008859 change Effects 0.000 claims description 4
- 230000003247 decreasing effect Effects 0.000 claims description 4
- 239000003079 shale oil Substances 0.000 claims description 4
- 239000002775 capsule Substances 0.000 claims description 3
- 238000004140 cleaning Methods 0.000 claims description 3
- 239000000835 fiber Substances 0.000 claims description 3
- 229920000642 polymer Polymers 0.000 claims description 3
- 239000004094 surface-active agent Substances 0.000 claims description 3
- 230000009194 climbing Effects 0.000 claims description 2
- 239000004744 fabric Substances 0.000 claims description 2
- 238000012216 screening Methods 0.000 claims 2
- 241000894006 Bacteria Species 0.000 claims 1
- 230000000694 effects Effects 0.000 abstract description 23
- 238000004519 manufacturing process Methods 0.000 abstract description 7
- 238000005516 engineering process Methods 0.000 description 13
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 11
- 238000009533 lab test Methods 0.000 description 5
- 238000011156 evaluation Methods 0.000 description 4
- 230000006641 stabilisation Effects 0.000 description 4
- 238000011105 stabilization Methods 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 239000007943 implant Substances 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 238000005457 optimization Methods 0.000 description 3
- 230000001360 synchronised effect Effects 0.000 description 3
- 230000002411 adverse Effects 0.000 description 2
- 239000003638 chemical reducing agent Substances 0.000 description 2
- 238000007796 conventional method Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 238000004146 energy storage Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 229910052500 inorganic mineral Inorganic materials 0.000 description 2
- 238000002955 isolation Methods 0.000 description 2
- 239000011707 mineral Substances 0.000 description 2
- 239000004570 mortar (masonry) Substances 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 239000002562 thickening agent Substances 0.000 description 2
- QGZKDVFQNNGYKY-UHFFFAOYSA-O Ammonium Chemical compound [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 description 1
- 241000169624 Casearia sylvestris Species 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- 229920000297 Rayon Polymers 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 238000005452 bending Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 235000009508 confectionery Nutrition 0.000 description 1
- 239000000470 constituent Substances 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 235000013399 edible fruits Nutrition 0.000 description 1
- 230000035800 maturation Effects 0.000 description 1
- 239000003094 microcapsule Substances 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 238000013439 planning Methods 0.000 description 1
- 238000005498 polishing Methods 0.000 description 1
- 238000012913 prioritisation Methods 0.000 description 1
- 239000010453 quartz Substances 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 238000012795 verification Methods 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
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/665—Compositions based on water or polar solvents containing inorganic compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
- C09K8/706—Encapsulated breakers
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/26—Gel breakers other than bacteria or enzymes
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
Abstract
The present invention provides a kind of horizontal well fracturing method, the described method includes implement N number of load fluid injection stage successively, wherein, the bulk density for the proppant that 1 load fluid injection stage of N uses before n-th load fluid injection stage is less than using the bulk density of proppant, the N are the natural number more than 1.Further, the fracturing fluid that n-th load fluid injection stage uses selects the ratio between storage modulus and Loss modulus in (2.0 5.0):1 fracturing fluid.The method of the present invention is by improving the suspendability of proppant and/or fracturing fluid, ensure that the uniform of every cluster crack replaces effect, ensure per the uniform feed liquor in cluster crack and into sand, to reach fracturing fluid in full section cluster crack, synchronously broken glue returns row, replacement phenomenon occurred in horizontal well fracturing so as to reducing, improves effect after pressure and realizes the maximization of stable production period.
Description
Technical field
The present invention relates to horizontal well fracturing technical field, and in particular to a kind of to reduce the horizontal well in segments pressure replaced
Cracking method, more particularly to it is hypotonic with reducing replacement in tight sand, carbonate rock, shale and coal petrography fractured horizontal well field
Horizontal well fracturing method.
Background technology
At present, horizontal well fracturing technology has become the hypotonic master with tight sand, carbonate rock, shale or even coal petrography
Body development technique, and huge economic benefit and social benefit have been played in production practices.It is necessary in the technology work progress
Replaced using high viscose liquid, but it is different from vertical well fracture, and all there is cross replacement phenomenon, some mistakes for horizontal well fracturing technology
More than 2 times up to normal value of replacement amount.Either bore hole sliding sleeve or bridge plug perforation combined tech, to prevent horizontal wellbore from sinking
The adverse effect that sand is setting to pitching or bridge plug is setting, is even excessively replaced with high viscosity glue sometimes.This is to horizontal well point
The protection of the fracture support section of section pressure break is extremely disadvantageous, can also seriously affect effect after pressure.Mining site is frequently found level
The actual fracturing effect of well not reaches expected simulation and forecast as a result, main cause may just be derived from this.
For technical standpoint, presently found had the main reason for replacement and had：1) horizontal wellbore diameter only has 200
More millimeters, it is allowed to which the settling height of proppant is limited；2) density of proppant is bigger than normal for fracturing fluid, the body as
Product density is all in 1.7g/cm3More than, much larger than the 1.03g/cm of fracturing fluid3；3) pad of frac design flow is bigger than normal, is split after termination of pumping
Seam continues to extend, and especially quartz is even more so when brittle mineral content is high.
The adverse effect replaced to fracturing effect is crossed, is mainly had：1) the serious water conservancy diversion for reducing nearly pit shaft crack at initial stage after pressure
Ability, causes nearly well fracture condudtiviy to completely lose, so-called " making dumplings " effect of generation；2) such as synchronous broken glue control not
Good, aquation breaks glue to the fracturing fluid of first fracturing section in advance, and leak-off causes greatly crack to close too early, the benefit to nearly well fracture condudtiviy
The measure of rescuing brings fatal influence；3) method for taking the uniform perforation of every cluster in the past, causes splitting for difference cluster during same section of pressure break
Stitched displacement effect difference, closer to pit shaft to cross replacement amount more, play every contribution of the shower hole to yield without balanced.
In conclusion a kind of horizontal well fracturing new technology that can reduce replacement amount by a relatively large margin of exploitation is pressed with realizing
The maximization of effect and stable production period will have significant realistic meaning afterwards.
The content of the invention
It is an object of the invention to provide it is a kind of can reduce or prevent replace horizontal well fracturing new technology, especially
It is hypotonic with reducing the horizontal well in segments replaced in tight sand, carbonate rock, shale and coal petrography fractured horizontal well field
Fracturing process, with improve press after effect and realize the maximization of stable production period.
The Basic Design thinking of the present invention and aim at, during fractured horizontal well, by improving the outstanding of proppant
Buoyancy energy, reduces in horizontal well fracturing and replacement phenomenon occurred.Further, can also be by improving the suspension of fracturing fluid
, shower hole density or TSOP fracturing etc. can be optimized, ensured per the uniform feed liquor in cluster crack and into sand, to reach full section cluster crack internal pressure
Splitting liquid, synchronously broken glue returns row, and replacement phenomenon occurred so as to further reduce in horizontal well fracturing.
According to the present invention, there is provided a kind of horizontal well fracturing method, including implement N number of load fluid injection rank successively
Section, wherein, the bulk density for the proppant that n-th load fluid injection stage uses is less than N-1 load fluid injection stage before
The bulk density of the proppant used；The N is the natural number more than 1.I.e. in fracturing process provided by the invention, last
One sand uses low-density propping agent than the stage.
N represents the N number of load fluid implant operation stage successively carried out in pressing crack construction process.According to the present invention, the value of N
It can be selected according to the practice of construction such as the lithology of oil well, reservoir parameter, construction requirement situation.For example, N can be oneself in 2-7
So number；Specifically, N can be 2,3,4 or 5 etc..
In construction, it is suitable with normal replacement amount that n-th load fluid injection stage typically refers to load fluid injection rate, that is, takes
The sand liquid injection rate load fluid implant operation stage suitable with wellbore volume.
Preferably, the bulk density for the proppant that n-th load fluid injection stage uses is in 1.2g/cm3Hereinafter, preferably
1.2-0.8g/cm3, such as 1.05-1.15g/cm3。
It is further preferred that the proppant that uses of n-th load fluid injection stage is 1.05-1.5g/ selected from bulk density
cm3Low-density propping agent, bulk density be less than 1.05g/cm3(such as 1.05-0.80g/cm3) super-low-density proppant and from
The one or more of suspended prop.The dosage of proppant is preferably the support in the mortar all replaced with replacement amount equivalent
Agent quantity, can be counted according to pit shaft total measurement (volume) (the medium position point of every section of perforated interval calculates) and last construction sand liquor ratio height
Calculate and obtain.
Described to be also referred to as from suspended prop from suspension fracturing propping agents, there is no particular limitation as to it in the present invention, this
It is common in field to be applied both to the present invention from suspended prop.
In method provided by the invention, from proppant angle, low-density/extremely-low density is hot on the trail of adding the final stage of sand
Proppant and new from suspended prop, can improve the suspendability of proppant, and then help to be reduced or avoided follow-up
Replacement construction in replacement phenomenon occurred.
According to the preferred embodiment of the present invention, the energy storage mould for the fracturing fluid that the n-th load fluid injection stage uses
The ratio between amount and Loss modulus are at (2.0-5.0):1, preferably (2.1-4.0):1, preferably (2.5-3.0):1.The energy storage mould of fracturing fluid
Amount is measured and adjusted by conventional method by those skilled in the art with Loss modulus, and details are not described herein.
Preferably, the ratio between the storage modulus for the fracturing fluid that n-th load fluid injection stage uses and Loss modulus are more than it
The ratio between the storage modulus for the fracturing fluid that preceding N-1 load fluid injection stage uses and Loss modulus.In the prior art, entirely taking
In the sand liquid implant operation stage, the ratio between the storage modulus of the fracturing fluid used and Loss modulus are generally 2:Less than 1.Therefore, at this
Invent in some embodiments, before the storage modulus for the fracturing fluid that N-1 load fluid injection stage uses and Loss modulus it
Than 2:Less than 1.
Further say, the glutinous bullet coefficient for the fracturing fluid that n-th load fluid injection stage uses takes sand for N-1 more than before
The glutinous bullet coefficient for the fracturing fluid that liquid injection stage uses.The increased pressure of viscoelasticity in hot pursuit is used than the stage in last sand
Split liquid.
According to the present invention, implement to replace construction after n-th load fluid injection stage.
According to the preferred embodiment of the present invention, the fracturing fluid (pressure break i.e. in hot pursuit that n-th load fluid injection stage uses
Liquid) it is preferably surfactant fracturing fluid, cleaning polymer fracturing fluid or fiber fracturing liquid.
According to the present invention, in N-1 load fluid injection stage before, for hypotonic and tight sand, carbonate rock
With coal petrography pressure break, the viscosity of fracturing fluid is in 50-100mPa.s；Split for shale oil air pressure, fracturing fluid viscosity in 2-40mPa.s,
Preferably, in 2-10mPa.s if fracturing fluid is slippery water, if fracturing fluid is glue in 20-40mPa.s.
On the basis of fracturing fluid seam and outstanding grittiness energy is met, the viscosity of fracturing fluid is lower, is more split beneficial to every section of cluster
Uniform feed liquor between seam and into sand.In general, at pressure break initial stage using the fracturing fluid of as above viscosity scope.On this basis,
In the last load fluid stage suitable with normal replacement amount, the good surfactant fracturing fluid of viscoelasticity, cleaning polymer pressure break are used instead
Liquid or fiber fracturing liquid.In general, the ratio between storage modulus and Loss modulus should maintain more than 2 times, to further improve pressure
The outstanding grittiness of liquid is split, prevents the sand setting effect of horizontal wellbore.
The specific formula of above-mentioned fracturing fluid in hot pursuit and the prioritization scheme of dosage, can combine actual core data and indoor comprehensive
Evaluation results determine.
According to the present invention, in N-1 load fluid injection stage before, (refer generally to hypotonic with causing for conventional lithology
Close sandstone, carbonate rock and coal petrography) pressure break, proppant uses 70-140 mesh and 20-40 mesh proppants；For shale gas pressure break,
Proppant uses three kinds of 70-140 mesh, 40-70 mesh and 30-50 mesh proppants.Make in N-1 load fluid injection stage before
Proppant is conventional use of proppant in state of the art, and bulk density is larger, generally in 1.5g/cm3More than.
A small amount of 70-140 mesh proppants can be selected in the proppant of conventional lithology pressure break, and to polish, nearly well crack tortuosity rubs
Resistance；Shale gas fracturing propping agents generally select 70-140 mesh proppants, and such proppant dosage is big, it is except nearly well crack of polishing
Bending friction, also supports microcrack effect.
The specific preferred properties requirement of proppant can be determined with reference to indoor comprehensive Evaluation results.
According to the preferred embodiment of the present invention, in pressing crack construction process, TSOP fracturing is all carried out to every section of perforation cluster
The TSOP fracturing pressure break of pressure break, preferably synchronization implementation based on filter loss and the TSOP fracturing pressure break based on flaw size.
Preferably, the construction sand liquor ratio of the TSOP fracturing pressure break based on flaw size passes through trial-and-error method foundation well head pressure
Power rate of change is screened, and preferably makes well head pressure climbing speed in more than 6MPa/min, preferably 6-25MPa/min, more excellent
Select the construction sand liquor ratio of 8-20MPa/min.In certain embodiments, the sand liquor ratio for example can be 16-26%.
From process parameter optimizing angle, it is ensured that per the uniform feed liquor in cluster crack with into sand, appropriate low viscosity with it is suitably low
Discharge capacity combination measure, this target easy to implement, and high viscosity and high discharge capacity combination, may make close to pit shaft cluster crack lose
Go sufficient feed liquor with into sand chance.Every section of design and construction technology for all carrying out TSOP fracturing pressure break is taken, can prevent termination of pumping
Afterwards crack continue development length it is excessive and caused by uncontrollable effect；At this time, fracture tip has stopped extending, and is pushed up even if part is crossed
Replace, because significantly being lifted into seam resistance, fracture width can only be brought to continue to increase, chance of the proppant to seam length direction extension
Then it is greatly lowered.On the basis of the overall fluid loss coefficient of every section of cluster reservoir of exact evaluation, the machine of two kinds of TSOP fracturings is taken
Reason synchronization implementation can increase the probability of TSOP fracturing realization；First, by the TSOP fracturing effect of the big generation of leak-off, second, leaning on slit width
The TSOP fracturing effect of narrow generation.
TSOP fracturing pressure break based on filter loss is designed with reference to leakoff coefficent, and TSOP fracturing pressure break has relied on leakoff coefficent
There is the Process planning flow of maturation, do not go to live in the household of one's in-laws on getting married herein.As for the narrow caused TSOP fracturing technology of slit width, the method that trial and error can be taken,
First constructed with a certain higher construction sand liquor ratio, pressure response feature observed after the sand liquor ratio mortar enters stratum,
As unit interval (min) interior rate of pressure rise is less than 1MPa/min, illustrate that the sand liquor ratio is not reaching to TSOP fracturing effect；But
Rate of pressure rise under such as a certain construction sand liquor ratio is much larger than 1MPa/min, then there occurs sand in nearly pit shaft crack for explanation
It is stifled, do not meet the design concept of TSOP fracturing yet.Thus by repeatedly exploratory plus sand test, can obtain optimal can reach end
The construction sand liquor ratio of portion's sand fallout effect.
Synchronous broken glue technology is to make up the Optimal action of displacement effect.By the gel breaker for optimizing every section of crack fracturing fluid
Thus concentration profile, final goal are to ensure that in all sections of cluster cracks that the row's of returning moment, thoroughly broken glue returned row to fracturing fluid after pressure, can be
Passive situation caused by making up replacement.
In the present invention, non-homogeneous simultaneous techniques takes another step.According to the preferred embodiment of the present invention, applied in pressure break
During work, glue method is broken using non-homogeneous synchronization and carries out brokenly glue, the gel breaker that preferably every section of perforation cluster fracturing fluid uses contains weight
It is 3-1 to measure ratio：1, preferably 1:1 non-capsule-type ammonium persulfate and capsule-type ammonium persulfate；And design non-capsule-type ammonium persulfate
Replace injection construction parameter with capsule-type ammonium persulfate so that capsule-type ammonium persulfate and non-glue were realized on fracture height section
Bladder type ammonium persulfate is alternately distributed.Even if non-capsule-type ammonium persulfate breaks glue, proppant settles, but capsule-type ammonium persulfate
Not synchronous broken glue, therefore, the support section of proppant in the vertical is further improved.
In the present invention, the non-capsule-type ammonium persulfate refers to the capsule breaker for including ammonium persulfate, does not have to it
Especially limitation, ammonium persulfate capsule breaker commonly used in the art are all applicable.The capsule-type ammonium persulfate can also be
Ammonium persulfate microcapsule degelling agent.
According to the preferred embodiment of the present invention, the described method includes carrying out pressing preceding evaluating reservoir before pressing crack construction,
It is preferred that evaluating reservoir includes obtaining brittleness index, rock mechanics parameters, Characteristics of The Matural Fractures parameter and comprehensive leak-off before the pressure
Coefficient.
Before pressure evaluating reservoir with compressibility be evaluated as core, especially overall fluid loss coefficient it is definite it is particularly important that, its close
It is that can really be realized to follow-up TSOP fracturing fracturing technique.Overall fluid loss coefficient can be according to conventional geology, well logging, record
The methods of well, core experiment and small scale fracturing test (especially analysis of pressure drop data), obtains, and is all conventional method, herein not
It is superfluous.Preferably, all data want the check of field measurement data to be applied again as far as possible, as dessert predicts that best incorporated is once
Or aerogenesis (liquid) section result carries out contrast verification after multiple pressure.
Result based on evaluating reservoir before pressure determines geology and the double dessert positions of engineering, and designs perforation cluster position and divide
Cloth.In general, brittleness is better, number of clusters should be more.It is preferred that the perforation cluster distribution is designed according to brittleness index, and work as brittleness
When index is less than 65%, every section of perforated interval design 2-4 showers hole, when brittleness index is more than 65%, every section of perforated interval designs 4 clusters
Or more (such as 4-6 clusters) perforation；It is preferred that 25~30m of cluster spacing.
From cluster perforation optimization angle, to ensure the uniform replacement effect per cluster crack, design becomes shot density.According to this hair
Bright preferred embodiment, the shot density of perforation cluster are successively decreased along pit shaft direction, and in the scope of 8-24 holes/rice；It is preferred that every section
The perforation sum of perforated interval is in 45-75 holes, preferably 50-70 holes.I.e. closer to the cluster of pit shaft, shot density it is lower (such as 10 holes/
Rice), on the contrary it is higher, such as 16-20 holes/rice.In the case of fracturing fluid discharge capacity is more than 15m3/min, the perforation sum of every section of perforated interval
In 60-70 holes.
As for from close to pit shaft calculate, per cluster perforation density design, to integrate according to this section of average viscosity, discharge capacity and
Cluster spacing etc. is adjusted, and shot density scope may be designed as 8-24 holes/rice.Average viscosity and discharge capacity are higher, and cluster spacing is bigger,
The shot density of the cluster close to pit shaft can suitably be amplified.
Other flows that the method provided according to the present invention may relate to, including follow-up discharge opeing and ask production process, reference
The code of conventional horizontal well staged fracturing carries out.
In certain specific embodiments of the invention, there is provided a kind of horizontal well fracturing (optimization) method, including
Following steps：
1) carry out pressing preceding evaluating reservoir, obtain brittleness index, rock mechanics parameters, Characteristics of The Matural Fractures parameter and comprehensive filter
Lose coefficient；
2) based on evaluation result 1), geology and the double dessert positions of engineering are determined, and designs the distribution of perforation cluster, is then penetrated
Hole, wherein
When brittleness index is more than 65%, every section of perforated interval designs the perforation of 4 clusters or more,
The shot density of perforation cluster is successively decreased along pit shaft direction, and in the scope of 8-24 holes/rice,
The perforation sum of every section of perforated interval is in 45-75 holes, preferably 50-70 holes；
3) pump notes prepad fluid seam and implements N number of load fluid injection stage successively, wherein,
N is the natural number of 2-5；
In N-1 load fluid injection stage before, for hypotonic with tight sand, carbonate rock and coal petrography pressure break,
The viscosity of fracturing fluid is in 50-100mPa.s；Split for shale oil air pressure, fracturing fluid viscosity is in 2-40mPa.s, it is preferable that if pressure
It is slippery water then in 2-10mPa.s to split liquid, in 20-40mPa.s if fracturing fluid is glue；And
In n-th load fluid injection stage, using the ratio between storage modulus and Loss modulus 2:More than 1, preferably 2.0-
5.0:1, more preferably 2.5-3.0:1 fracturing fluid；
In N-1 load fluid injection stage before, for hypotonic and tight sand, carbonate rock and coal petrography pressure break
Proppant uses 70-140 mesh and 20-40 mesh proppants, and 70-140 mesh, 40-70 mesh are used for the proppant of shale gas pressure break
With three kinds of proppants of 30-50 mesh；And
Used in n-th load fluid injection stage and be selected from bulk density 1.05-1.5g/cm3Low-density propping agent, volume
Density is less than 1.05g/cm3Super-low-density proppant and one or more proppants from suspended prop；
4) construction is replaced；
5) TSOP fracturing pressure break all carries out TSOP fracturing pressure break to every section of perforation cluster, and preferably synchronization implementation is based on filter loss
TSOP fracturing pressure break and the TSOP fracturing pressure break based on flaw size；
The construction sand liquor ratio of the TSOP fracturing pressure break based on flaw size is by trial-and-error method according to rate of pressure change
Screened, and selection makes rate of pressure rise in the construction sand liquor ratio of 6-25MPa/min；
6) implement non-homogeneous synchronization and break glue
Glue method is broken using non-homogeneous synchronization and carries out brokenly glue, the gel breaker that preferably every section of perforation cluster fracturing fluid uses contains weight
Than for 3-1：1 non-capsule-type ammonium persulfate and capsule-type ammonium persulfate；And design non-capsule-type ammonium persulfate and capsule-type over cure
Sour ammonium alternately injects construction parameter so that realizes that non-capsule-type ammonium persulfate and capsule-type ammonium persulfate are handed on fracture height section
For distribution.
Above-mentioned steps 1) -6) in particular content or explanation be referred to it is described previously.It is above-mentioned in the case of enforceable
Step 1) -6) not necessarily carried out in strict accordance with some order, as long as can achieve the object of the present invention, the implementation time of above-mentioned steps
Sequence can be adjusted suitably.
Present invention also offers the fracture method for horizontal well as described above provided according to the present invention in hypotonic and fine and close sand
Application in rock, carbonate rock, shale or coal petrography fractured horizontal well.
The present invention has following technical characterstic and excellent results
The present invention provides it is a kind of prevented replace horizontal well fracturing new technology, be main pressure break important composition portion
Point, evaluating reservoir, shower hole conceptual design, fracturing fluid viscosity and viscoelasticity before the pressure of core are evaluated as with compressibility by carrying out
Design, proppant preferably, the optimization of pressure break injection parameter, non-homogeneous synchronization break glue technology, improve proppant and fracturing fluid
Suspendability, ensure that the uniform of every cluster crack replaces effect, ensure per the uniform feed liquor in cluster crack and into sand, to reach full section cluster
Synchronously broken glue returns row to fracturing fluid in crack, and replacement phenomenon occurred in horizontal well fracturing so as to reduce, improves effect after pressure
And realize the maximization of stable production period.This method design is reasonable, construction technology is simple, easy to operate, has in fractured horizontal well
Wide application prospect.
Embodiment
The present invention has been described in detail above, the present invention has been done furtherly with reference to specific embodiment
It is bright, it should be appreciated that the scope of the present invention is not limited to this.In the examples below, the step of explanation is not developed in details can be by this
Field technology personnel operate according to actual conditions.The components such as the drag reducer that is used in embodiment, thickening agent are without particular/special requirement.
Embodiment
River southeast well vertical depth 2298m, depth measurement 3623m, horizontal segment length 1060m.According to following construction parameter and step
Suddenly transformed.
Young's modulus, Poisson's ratio and crustal stress data are obtained according to the borehole logging tool data explanation results, by core experiment knot
Fruit corrects data above, selects high brittleness, gas-bearing property height, the position of good penetrability as reservoir "sweet spot".
It is 45%~55% to calculate dessert position brittleness index according to mineral constituent and mechanics parameter, every section of 2 clusters of design
(close 10 holes in hole/m, 16 holes/m)~3 cluster (close 10 holes in hole/m, 16 holes/m, 22 holes/m) perforation, and hole density is passed along pit shaft direction
Subtract；Cluster 25~30m of spacing, amounts to 16 sections.
Slippery water 3~6mPas of viscosity, glue fracturing fluid viscosity 30mPas are optimized using crack extended software Meyer,
The ratio between storage modulus and Loss modulus be 2.8, wherein, slippery water host agent be 0.05~0.1% drag reducer, glue fracturing fluid master
Agent is 0.3% thickening agent.
With reference to crack extended software and laboratory experiment, complex optimum proppant dosage and particle diameter are respectively：Taken above 3
Sand liquid injection stage uses 38m370-140 mesh, 20m340-70 mesh and 8m3Three kinds of proppant (bulk densities 1.63 of 30-50 mesh
~1.78g/cm3), use 5m in last load fluid injection stage (the 4th load fluid injection stage)3Extremely-low density supports
Agent (bulk density 1.02g/cm3).Proppant total amount is then 71m3。
The first stage of pressing crack construction is the prepad fluid seam stage, takes the slippery water of viscosity 3mPas.Expand with reference to crack
Open up software and laboratory experiment, complex optimum operational procedure are as follows：With 2m3The discharge capacity injection 15m of/min3Salt low-kappa number pit shaft；So
Afterwards with 2-14m3The discharge capacity injection 100m of/min3The slippery water of viscosity 3mPas.
The second stage of pressing crack construction expands the seam stage (first load fluid injection stage) for the low sand ratio of small particle proppant,
Take 4~5mPas of viscosity slippery water and 70-140 mesh proppant (bulk density is 1.63~1.78g/cm3).With reference to splitting
Stitch extended software and laboratory experiment, complex optimum operational procedure are as follows：Discharge capacity stabilization is in 14m3/ min, slug formula injection 70-140
Mesh proppant, proppant sand ratio are 2-12%, and isolation slug is 35m3.This stage injects the slippery water of 5~6mPas altogether
1310m3, 70-140 mesh proppants 38m3。
The phase III of pressing crack construction, (second load fluid injected rank for the medium size proppant high sand ratio joint filling stage
Section), take viscosity 6mPas slippery water and 40-70 mesh proppant (bulk density is 1.63~1.78g/cm3).With reference to splitting
Stitch extended software and laboratory experiment, complex optimum operational procedure are as follows：Discharge capacity stabilization is in 14m3/ min, slug formula injection 40-70
Mesh proppant, proppant sand ratio are followed successively by 14-16-18%, and isolation slug is 40m3.This stage injects the smooth of 6mPas altogether
Water 190m3, 40-70 mesh proppants 20m3。
The fourth stage of pressing crack construction is the large scale proppant high sand ratio joint filling stage (the 3rd load fluid injection stage),
Take viscosity 30mPas glue and 30-50 mesh proppant (bulk density is 1.63~1.78g/cm3).Extended with reference to crack
Software and laboratory experiment, complex optimum operational procedure are as follows：Discharge capacity stabilization is in 14m3/ min, injection sand is than the 30-50 for 20%
Mesh Proppant Slugs.This stage injects the glue 40m of 30mPas altogether3, 30-50 mesh proppants 8m3。
5th stage of pressing crack construction blocks the sealing stage (the 4th load fluid injection stage) for super-low-density proppant,
Take the glue and 30-50 mesh super-low-density proppant (bulk density 1.02g/cm of viscosity 30mPas3).In work progress,
Multiple field practice show, and 22% sand ratio is 8~15MPa/min into rate of pressure rise in the unit interval behind stratum, is applied
Work latter stage adds the sand stage using the sand ratio as last, is replaced afterwards.Operational discharge capacity stabilization is in 14m3/ min, injection
Super-low-density proppant slug of the sand than the 30-50 mesh for 22%.This stage injects the glue 23m of 30mPas altogether3, 30-50
Mesh super-low-density proppant 5m3。
Broken glue is constructed, in the gel breaker of every section of cluster fracturing fluid, conventional ammonium persulfate and capsule-type ammonium persulfate gel breaker
Ratio is 1:1, the 1st grade of gel breaker dosage 0.02%, subsequently increases by 0.004% step by step.
Carry out the row of returning and ask production.
By the implementation of the method for the present invention, replacement phenomenon will be crossed and fall below minimum, effect after pressure is improved and realize stable yields
The maximization of phase.Open-flow capacity is 22.5 × 10 after the well pressure4m3, than same platform offset well output increased 12%.
Although the present invention has been described in detail, it will be understood by those skilled in the art that in spirit and scope of the invention
Modification will be apparent.However, it should be understood that each side of the invention recorded, different embodiments
Each several part and the various features enumerated can be combined or all or part of exchange.In above-mentioned each embodiment, that
A little embodiments with reference to another embodiment can be combined suitably with other embodiment, this is by by this area skill
Art personnel are to understand.In addition, it will be understood to those of skill in the art that description above is only exemplary mode, not purport
In the limitation present invention.
Claims (12)
- A kind of 1. horizontal well fracturing method, it is characterised in that the described method includes implement N number of load fluid injection rank successively Section, wherein, the bulk density for the proppant that n-th load fluid injection stage uses is less than N-1 load fluid injection stage before The bulk density of the proppant used, the N are the natural number more than 1.
- 2. the according to the method described in claim 1, it is characterized in that, body for the proppant that n-th load fluid injection stage uses Product density is in 1.2g/cm3Hereinafter, preferably 1.2-0.8g/cm3；It is preferred that the proppant that n-th load fluid injection stage uses is selected from Bulk density 1.05-1.5g/cm3Low-density propping agent, bulk density be less than 1.05g/cm3Super-low-density proppant and from One or more in suspended prop.
- 3. method according to claim 1 or 2, it is characterised in that the fracturing fluid that n-th load fluid injection stage uses The ratio between storage modulus and Loss modulus are at (2.0-5.0):1, preferably (2.5-3.0):1；Preferably, n-th load fluid injection rank The fracturing fluid that N-1 load fluid injection stage uses before the ratio between the storage modulus for the fracturing fluid that section uses and Loss modulus are more than Storage modulus and the ratio between Loss modulus.
- 4. method according to any one of claim 1-3, it is characterised in that in pressing crack construction process, penetrated to every section Hole cluster all carries out TSOP fracturing pressure break, preferably TSOP fracturing pressure break of the synchronization implementation based on filter loss and the end based on flaw size Portion's decolorizing bacteria；The construction sand liquor ratio of the further preferably described TSOP fracturing pressure break based on flaw size passes through trial-and-error method foundation The screening of well head pressure rate of change makes well head pressure climbing speed in the construction sand liquor ratio of 6-25MPa/min.
- 5. according to the described method of any one of claim 1-4, it is characterised in that in pressing crack construction process, using non-equal Even synchronization breaks glue method and carries out brokenly glue, and it is 3-1 that the gel breaker that preferably every section of perforation cluster fracturing fluid uses, which contains weight ratio,：1 non-glue Bladder type ammonium persulfate and capsule-type capsule ammonium persulfate；And design non-capsule-type ammonium persulfate and replace note with capsule-type ammonium persulfate Enter construction parameter so that realize that non-capsule-type ammonium persulfate and capsule-type ammonium persulfate are alternately distributed on fracture height section.
- 6. according to the method any one of claim 1-5, it is characterised in that the described method includes before pressing crack construction Carry out pressing preceding evaluating reservoir, evaluating reservoir includes obtaining brittleness index, rock mechanics parameters, intrinsic fracture spy before preferably described pressure Levy parameter and overall fluid loss coefficient.
- 7. according to the method described in claim 6, it is characterized in that, the result based on evaluating reservoir before pressure determines geology and engineering Double dessert positions, and design the distribution of perforation cluster；It is preferred that the perforation cluster distribution is designed according to brittleness index, and work as brittleness index During less than 65%, every section of perforated interval design 2-4 showers hole, when brittleness index is more than 65%, every section of perforated interval design 4 clusters or with On perforation.
- 8. the method according to the description of claim 7 is characterized in that the shot density of perforation cluster is successively decreased along pit shaft direction, and The scope of 8-24 holes/rice；It is preferred that the perforation sum of every section of perforated interval is in 45-75 holes, preferably 50-70 holes；More preferably in fracturing fluid Discharge capacity is more than 15m3In the case of/min, the perforation sum of every section of perforated interval is in 60-70 holes.
- 9. according to the method any one of claim 1-8, it is characterised in that the n-th load fluid injection stage makes Fracturing fluid is surfactant fracturing fluid, cleaning polymer fracturing fluid or fiber fracturing liquid.
- 10. according to the method any one of claim 1-9, it is characterised in that the N-1 load fluid injection before described In stage, for hypotonic and tight sand, carbonate rock and coal petrography pressure break, the viscosity of fracturing fluid is in 50-100mPa.s；For page Shale oil air pressure is split, and fracturing fluid viscosity is in 2-40mPa.s；And/orBefore described in N-1 load fluid injection stage, for hypotonic with tight sand, carbonate rock and coal petrography pressure break, make With 70-140 mesh and 20-40 mesh proppants；For shale gas pressure break, three kinds of 70-140 mesh, 40-70 mesh and 30-50 mesh branch are used Support agent.
- 11. a kind of horizontal well fracturing method, comprises the following steps：1) brittleness index, rock mechanics parameters, Characteristics of The Matural Fractures parameter and overall fluid loss coefficient are obtained；2) step 1) is based on, determines geology and the double dessert positions of engineering, and designs the distribution of perforation cluster, then perforation, wherein,When brittleness index is less than 65%, every section of perforated interval design 2-4 showers hole, when brittleness index is more than 65%, every section is penetrated Hole section design 4-6 showers hole,The shot density of perforation cluster is successively decreased along pit shaft direction, and in the scope of 8-24 holes/rice,The perforation sum of every section of perforated interval is in 45-75 holes；3) pump notes prepad fluid seam and implements N number of load fluid injection stage successively, wherein,N is the natural number of 2-5；In N-1 load fluid injection stage before, for hypotonic and tight sand, carbonate rock and coal petrography pressure break, pressure break The viscosity of liquid is split, fracturing fluid viscosity is in 2-40mPa.s for shale oil air pressure in 50-100mPa.s；AndIn n-th load fluid injection stage, using the ratio between storage modulus and Loss modulus in 2.0-5.0:1 fracturing fluid；In N-1 load fluid injection stage before, for hypotonic and tight sand, carbonate rock and coal petrography pressure break, use 70-140 mesh and 20-40 mesh proppants, for shale gas pressure break, use three kinds of 70-140 mesh, 40-70 mesh and 30-50 mesh supports Agent；AndIn n-th load fluid injection stage, using selected from bulk density 1.05-1.5g/cm3Low-density propping agent, bulk density Less than 1.05g/cm3Super-low-density proppant and one or more proppants from suspended prop；4) construction is replaced；5) TSOP fracturing pressure breakAll carry out TSOP fracturing pressure break to every section of perforation cluster, preferably TSOP fracturing pressure break of the synchronization implementation based on filter loss and be based on The TSOP fracturing pressure break of flaw size；The construction sand liquor ratio of the TSOP fracturing pressure break based on flaw size is carried out by trial-and-error method according to rate of pressure change Screening, and selection makes rate of pressure rise in the construction sand liquor ratio of 6-25MPa/min；6) implement non-homogeneous synchronization and break glueGlue method is broken using non-homogeneous synchronization and carries out brokenly glue, it is 3-1 that the gel breaker that every section of perforation cluster fracturing fluid uses, which contains weight ratio,： 1 non-capsule-type ammonium persulfate and capsule-type ammonium persulfate；And design non-capsule-type ammonium persulfate and handed over capsule-type ammonium persulfate For injection construction parameter so that realize that non-capsule-type ammonium persulfate and capsule-type ammonium persulfate alternately divide on fracture height section Cloth.
- 12. the method according to claim 1-10 any one of them method or claim 11 is in hypotonic and fine and close sand Application in rock, carbonate rock, shale or coal petrography fractured horizontal well.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610956610.8A CN107989592B (en) | 2016-10-27 | 2016-10-27 | Staged fracturing method for horizontal well |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610956610.8A CN107989592B (en) | 2016-10-27 | 2016-10-27 | Staged fracturing method for horizontal well |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN107989592A true CN107989592A (en) | 2018-05-04 |
| CN107989592B CN107989592B (en) | 2020-04-07 |
Family
ID=62028458
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610956610.8A Active CN107989592B (en) | 2016-10-27 | 2016-10-27 | Staged fracturing method for horizontal well |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN107989592B (en) |
Cited By (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109281645A (en) * | 2018-09-30 | 2019-01-29 | 重庆长江造型材料（集团）股份有限公司 | Using the construction method from suspension riverfrac treatment proppant |
| CN109944578A (en) * | 2019-02-27 | 2019-06-28 | 中国石油天然气股份有限公司 | Preparation method and construction process of prefabricated fracturing displacement isolator |
| CN110700806A (en) * | 2018-06-25 | 2020-01-17 | 中国石油天然气股份有限公司 | Fracturing design method and device for low-permeability oil reservoir |
| 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 |
| CN111236914A (en) * | 2020-01-19 | 2020-06-05 | 中国石油大学(北京) | Horizontal well multi-fracture fracturing method |
| CN112302611A (en) * | 2019-07-25 | 2021-02-02 | 中国石油天然气股份有限公司 | Method for filling and staged fracturing of multi-particle-size combined proppant |
| CN112302604A (en) * | 2019-07-31 | 2021-02-02 | 中国石油化工股份有限公司 | Horizontal well subsection repeated fracturing method and application thereof |
| CN112343560A (en) * | 2019-08-07 | 2021-02-09 | 中国地质调查局水文地质环境地质调查中心 | Fracturing and sand prevention combined process method for exploiting low-permeability reservoir natural gas hydrate |
| CN112343569A (en) * | 2019-08-06 | 2021-02-09 | 中国石油化工股份有限公司 | Horizontal well fracturing method for promoting multiple clusters of fractures by multiple acid injection and temporary plugging |
| CN113513295A (en) * | 2020-04-10 | 2021-10-19 | 中国石油化工股份有限公司 | Method for improving uniform extension and support of multiple clusters of cracks in section |
| CN114881230A (en) * | 2022-07-11 | 2022-08-09 | 成都创源油气技术开发有限公司 | Fracturing fluid flowback intelligent control system and equipment |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103089224A (en) * | 2011-10-28 | 2013-05-08 | 中国石油化工股份有限公司 | Fracturing method for comprehensively controlling fracture height |
| WO2014204709A2 (en) * | 2013-06-21 | 2014-12-24 | Praxair Technology, Inc. | Fracturing fluid composition and method of using same in geological formations |
| CN104449649A (en) * | 2014-11-28 | 2015-03-25 | 中国石油化工股份有限公司胜利油田分公司采油工艺研究院 | High-concentration water-in-oil emulsion-state associating polymer fracturing fluid and preparation method thereof |
| CN105778884A (en) * | 2016-05-10 | 2016-07-20 | 西南石油大学 | Supramolecular polymer clean fracturing fluid resistant to high temperature of 170 DEG C |
-
2016
- 2016-10-27 CN CN201610956610.8A patent/CN107989592B/en active Active
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103089224A (en) * | 2011-10-28 | 2013-05-08 | 中国石油化工股份有限公司 | Fracturing method for comprehensively controlling fracture height |
| WO2014204709A2 (en) * | 2013-06-21 | 2014-12-24 | Praxair Technology, Inc. | Fracturing fluid composition and method of using same in geological formations |
| CN104449649A (en) * | 2014-11-28 | 2015-03-25 | 中国石油化工股份有限公司胜利油田分公司采油工艺研究院 | High-concentration water-in-oil emulsion-state associating polymer fracturing fluid and preparation method thereof |
| CN105778884A (en) * | 2016-05-10 | 2016-07-20 | 西南石油大学 | Supramolecular polymer clean fracturing fluid resistant to high temperature of 170 DEG C |
Non-Patent Citations (1)
| Title |
|---|
| 唐瑞江等: ""元坝气田ＨＦ－１陆相深层页岩气井"", 《天然气工业》 * |
Cited By (14)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110700806A (en) * | 2018-06-25 | 2020-01-17 | 中国石油天然气股份有限公司 | Fracturing design method and device for low-permeability oil reservoir |
| CN109281645A (en) * | 2018-09-30 | 2019-01-29 | 重庆长江造型材料（集团）股份有限公司 | Using the construction method from suspension riverfrac treatment proppant |
| 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 |
| CN109944578A (en) * | 2019-02-27 | 2019-06-28 | 中国石油天然气股份有限公司 | Preparation method and construction process of prefabricated fracturing displacement isolator |
| CN112302611A (en) * | 2019-07-25 | 2021-02-02 | 中国石油天然气股份有限公司 | Method for filling and staged fracturing of multi-particle-size combined proppant |
| CN112302604A (en) * | 2019-07-31 | 2021-02-02 | 中国石油化工股份有限公司 | Horizontal well subsection repeated fracturing method and application thereof |
| CN112302604B (en) * | 2019-07-31 | 2023-01-24 | 中国石油化工股份有限公司 | Horizontal well subsection repeated fracturing method and application thereof |
| CN112343569A (en) * | 2019-08-06 | 2021-02-09 | 中国石油化工股份有限公司 | Horizontal well fracturing method for promoting multiple clusters of fractures by multiple acid injection and temporary plugging |
| CN112343569B (en) * | 2019-08-06 | 2023-02-28 | 中国石油化工股份有限公司 | Horizontal well fracturing method for promoting multiple clusters of fractures by multiple acid injection and temporary plugging |
| CN112343560A (en) * | 2019-08-07 | 2021-02-09 | 中国地质调查局水文地质环境地质调查中心 | Fracturing and sand prevention combined process method for exploiting low-permeability reservoir natural gas hydrate |
| CN111236914A (en) * | 2020-01-19 | 2020-06-05 | 中国石油大学(北京) | Horizontal well multi-fracture fracturing method |
| CN113513295A (en) * | 2020-04-10 | 2021-10-19 | 中国石油化工股份有限公司 | Method for improving uniform extension and support of multiple clusters of cracks in section |
| CN114881230A (en) * | 2022-07-11 | 2022-08-09 | 成都创源油气技术开发有限公司 | Fracturing fluid flowback intelligent control system and equipment |
Also Published As
| Publication number | Publication date |
|---|---|
| CN107989592B (en) | 2020-04-07 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107989592A (en) | A kind of horizontal well fracturing method | |
| CN110608024B (en) | Volume fracturing method for improving filling efficiency of micro-support system by deep shale gas | |
| CN107503729B (en) | A kind of micro- support fracturing method improving pressure break stationary phase | |
| CN107965305B (en) | Layered repeated fracturing method | |
| CN110761763B (en) | Horizontal well repeated fracturing method | |
| CN109958416B (en) | Multi-cluster perforation fracturing method for uniformly feeding liquid and sand with variable aperture and variable pore density | |
| CN109751029B (en) | Deep shale gas fracturing method | |
| CN107965306B (en) | Acid injection fracturing method | |
| CN109958426A (en) | A kind of fracturing process improving deep layer shale gas crack complexity | |
| CN109958424A (en) | A method of realizing that hydraulic fracture end effectively blocks | |
| CN107387053A (en) | A kind of method that big passage major fracture cooperates with pressure break with complicated seam net | |
| CN108952668B (en) | Fracturing method of normal-pressure shale gas reservoir | |
| CN112253066B (en) | Method for improving fracture complexity and transformation volume of deep shale gas | |
| CN109751037A (en) | A kind of normal pressure shale gas reservoir high frequency change displacement volume fracturing process | |
| CN109958425A (en) | A kind of deep layer shale gas improves the fracturing process of multi-scale facture rupture | |
| CN109751035A (en) | A kind of oil-gas reservoir fracturing sand feeding method | |
| CN105604534A (en) | Hydraulically affected fracturing process method for increasing production of coal-bed gas reservoir | |
| CN110344799A (en) | A kind of critical sand plug fracturing process improving crack complexity | |
| CN108952655A (en) | A kind of normal pressure shale gas sieve tube completion water-jet volume fracturing method | |
| CN109424346A (en) | A kind of stepless variable element ramp type injection fracturing process of deep layer shale gas | |
| CN109751025A (en) | A kind of fracturing process improving deep layer shale gas full size fracture support volume | |
| CN109751032A (en) | A kind of more partial size mixed with proppants fracturing process | |
| CN108661616B (en) | Layered fracturing method suitable for sandstone oil and gas reservoir | |
| CN106321044A (en) | Proppant-carrying acid fracturing method for high-temperature ultra-deep carbonate reservoir | |
| CN110424939A (en) | A method of increasing gneiss oil-gas reservoir and stitches net volume fracturing effect |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |