CN102925133A - Fracturing fluid and fracturing method for controlling fracture extension height - Google Patents
Fracturing fluid and fracturing method for controlling fracture extension height Download PDFInfo
- Publication number
- CN102925133A CN102925133A CN2012103924290A CN201210392429A CN102925133A CN 102925133 A CN102925133 A CN 102925133A CN 2012103924290 A CN2012103924290 A CN 2012103924290A CN 201210392429 A CN201210392429 A CN 201210392429A CN 102925133 A CN102925133 A CN 102925133A
- Authority
- CN
- China
- Prior art keywords
- fracturing
- fiber
- sand
- fibre
- fracturing liquid
- 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 57
- 239000012530 fluid Substances 0.000 title claims abstract description 40
- 239000000835 fiber Substances 0.000 claims abstract description 108
- 239000004576 sand Substances 0.000 claims abstract description 65
- 239000007788 liquid Substances 0.000 claims description 90
- 239000003795 chemical substances by application Substances 0.000 claims description 73
- 230000008569 process Effects 0.000 claims description 38
- 230000015572 biosynthetic process Effects 0.000 claims description 18
- 241001449342 Chlorocrambe hastata Species 0.000 claims description 16
- 239000002253 acid Substances 0.000 claims description 15
- 239000000463 material Substances 0.000 claims description 14
- 239000013505 freshwater Substances 0.000 claims description 12
- -1 polypropylene Polymers 0.000 claims description 12
- 230000008719 thickening Effects 0.000 claims description 12
- 239000000243 solution Substances 0.000 claims description 11
- 238000002347 injection Methods 0.000 claims description 7
- 239000007924 injection Substances 0.000 claims description 7
- 239000000919 ceramic Substances 0.000 claims description 6
- 238000009736 wetting Methods 0.000 claims description 6
- 239000004372 Polyvinyl alcohol Substances 0.000 claims description 4
- 229920002451 polyvinyl alcohol Polymers 0.000 claims description 4
- PEPBFCOIJRULGJ-UHFFFAOYSA-N 3h-1,2,3-benzodioxazole Chemical compound C1=CC=C2NOOC2=C1 PEPBFCOIJRULGJ-UHFFFAOYSA-N 0.000 claims description 3
- 229920002748 Basalt fiber Polymers 0.000 claims description 3
- 239000004132 Calcium polyphosphate Substances 0.000 claims description 3
- 229920000049 Carbon (fiber) Polymers 0.000 claims description 3
- 239000004698 Polyethylene Substances 0.000 claims description 3
- 229920000265 Polyparaphenylene Polymers 0.000 claims description 3
- 239000004743 Polypropylene Substances 0.000 claims description 3
- 229920004935 Trevira® Polymers 0.000 claims description 3
- 150000001408 amides Chemical class 0.000 claims description 3
- 235000019827 calcium polyphosphate Nutrition 0.000 claims description 3
- 239000004917 carbon fiber Substances 0.000 claims description 3
- 239000003365 glass fiber Substances 0.000 claims description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 3
- 229920002239 polyacrylonitrile Polymers 0.000 claims description 3
- 229920000573 polyethylene Polymers 0.000 claims description 3
- 229920001155 polypropylene Polymers 0.000 claims description 3
- 239000004814 polyurethane Substances 0.000 claims description 3
- 229920002635 polyurethane Polymers 0.000 claims description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 abstract description 52
- 230000000694 effects Effects 0.000 abstract description 13
- 239000010410 layer Substances 0.000 abstract 2
- 239000003431 cross linking reagent Substances 0.000 abstract 1
- 239000012784 inorganic fiber Substances 0.000 abstract 1
- 239000011229 interlayer Substances 0.000 abstract 1
- 239000002562 thickening agent Substances 0.000 abstract 1
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 60
- 239000000654 additive Substances 0.000 description 11
- 230000000996 additive effect Effects 0.000 description 11
- 229920002907 Guar gum Polymers 0.000 description 10
- 238000010276 construction Methods 0.000 description 10
- 239000000665 guar gum Substances 0.000 description 10
- 229960002154 guar gum Drugs 0.000 description 10
- 235000010417 guar gum Nutrition 0.000 description 10
- 238000003825 pressing Methods 0.000 description 9
- 238000005516 engineering process Methods 0.000 description 8
- 239000003381 stabilizer Substances 0.000 description 8
- 239000000203 mixture Substances 0.000 description 7
- 239000000839 emulsion Substances 0.000 description 6
- LZZYPRNAOMGNLH-UHFFFAOYSA-M Cetrimonium bromide Chemical compound [Br-].CCCCCCCCCCCCCCCC[N+](C)(C)C LZZYPRNAOMGNLH-UHFFFAOYSA-M 0.000 description 5
- 239000004927 clay Substances 0.000 description 5
- 239000011521 glass Substances 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- 239000000126 substance Substances 0.000 description 5
- 239000004094 surface-active agent Substances 0.000 description 5
- 239000004215 Carbon black (E152) Substances 0.000 description 4
- 229920002472 Starch Polymers 0.000 description 4
- 238000005452 bending Methods 0.000 description 4
- 229930195733 hydrocarbon Natural products 0.000 description 4
- 235000019698 starch Nutrition 0.000 description 4
- 244000007835 Cyamopsis tetragonoloba Species 0.000 description 3
- 230000008901 benefit Effects 0.000 description 3
- 125000001183 hydrocarbyl group Chemical group 0.000 description 3
- 230000009466 transformation Effects 0.000 description 3
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 2
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- XQCFHQBGMWUEMY-ZPUQHVIOSA-N Nitrovin Chemical compound C=1C=C([N+]([O-])=O)OC=1\C=C\C(=NNC(=N)N)\C=C\C1=CC=C([N+]([O-])=O)O1 XQCFHQBGMWUEMY-ZPUQHVIOSA-N 0.000 description 2
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 2
- 239000006004 Quartz sand Substances 0.000 description 2
- 230000000052 comparative effect Effects 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 239000006185 dispersion Substances 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 238000001802 infusion Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 229920002401 polyacrylamide Polymers 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 239000000843 powder Substances 0.000 description 2
- 239000010453 quartz Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 239000008107 starch Substances 0.000 description 2
- IAYPIBMASNFSPL-UHFFFAOYSA-N Ethylene oxide Chemical compound C1CO1 IAYPIBMASNFSPL-UHFFFAOYSA-N 0.000 description 1
- 208000035126 Facies Diseases 0.000 description 1
- 241000282326 Felis catus Species 0.000 description 1
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical class F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical class Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 239000013543 active substance Substances 0.000 description 1
- 235000019270 ammonium chloride Nutrition 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 239000011324 bead Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 238000009530 blood pressure measurement Methods 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 239000010430 carbonatite Substances 0.000 description 1
- 125000002057 carboxymethyl group Chemical group [H]OC(=O)C([H])([H])[*] 0.000 description 1
- 150000001768 cations Chemical class 0.000 description 1
- WOWHHFRSBJGXCM-UHFFFAOYSA-M cetyltrimethylammonium chloride Chemical compound [Cl-].CCCCCCCCCCCCCCCC[N+](C)(C)C WOWHHFRSBJGXCM-UHFFFAOYSA-M 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- GQOKIYDTHHZSCJ-UHFFFAOYSA-M dimethyl-bis(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C=CC[N+](C)(C)CC=C GQOKIYDTHHZSCJ-UHFFFAOYSA-M 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000002344 fibroplastic effect Effects 0.000 description 1
- 239000012467 final product Substances 0.000 description 1
- 239000003292 glue Substances 0.000 description 1
- KWIUHFFTVRNATP-UHFFFAOYSA-N glycine betaine Chemical compound C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 description 1
- 229920001519 homopolymer Polymers 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 235000011167 hydrochloric acid Nutrition 0.000 description 1
- 229920013818 hydroxypropyl guar gum Polymers 0.000 description 1
- 238000003475 lamination Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 229920000333 poly(propyleneimine) Polymers 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
- 229920003169 water-soluble polymer Polymers 0.000 description 1
Images
Landscapes
- Curing Cements, Concrete, And Artificial Stone (AREA)
Abstract
The invention relates to a fracturing fluid and a fracturing method for controlling fracture extension height, wherein the fracturing fluid is used as a sand carrying fluid, has viscosity of less than 10mPa.s, and comprises sand suspending fibers, the sand suspending fibers are selected from hydrophilic high-strength organic fibers or inorganic fibers, and the fracturing fluid does not contain a cross-linking agent. The fracturing fluid provided by the invention uses sand suspending fibers to form a three-dimensional network structure to suspend the proppant, so that the thickening agent can be replaced, and the effect of reducing the viscosity of the fracturing fluid is realized. The fracturing method of the invention uses the fracturing fluid to carry the proppant to be injected into the stratum under the condition of low discharge capacity, thereby effectively controlling the extension height of the fractured fracture. The fracturing fluid and the fracturing method are particularly suitable for fracturing and yield increase of oil and gas reservoirs of thin reservoir layers, and can particularly meet the fracturing requirements of the thin reservoir layers and the oil and gas reservoirs with bottom water or interlayer water.
Description
Technical field
The present invention relates to a kind of fracturing liquid and well fracturing method in the oil and gas exploitation technical field, be particularly related in the hydrocarbon-bearing pool fracturing process of thin reservoir, thereby utilize fiber to replace the guar gum suspended prop to reduce of the fracturing fluid viscosity, with the fracturing process of control fracturing fracture propagation height.
Background technology
China's Low Permeability Oil/gas stock number is huge, accounts for to verify more than 70% of total reserves, is the main potentiality work area of producing in the Future in China increasing the storage.This class hydrocarbon resources has three low characteristics, and low, the natural production rate of the rate of namely verifying is low, recovery ratio is low.Verified, the waterfrac treatment transformation is to improve the production capacity of low-permeability oil gas reservoir and the important technical of development effectiveness and benefit.But, for the low-permeability oil gas reservoir, generally having the characteristics that layer is many, layer is thin, some also exists end water and middle water, and conventional fracturing effect is poor.
Briefly, the principle of conventional hydraulic fracturing technology is as follows: it utilizes ground high-pressure pump group, with high-viscous liquid with in the discharge capacity Injection Well that substantially exceeds the formation absorption ability, produce high pressure in the shaft bottom, when this pressure during greater than the terrestrial stress of Around A Borehole and formation rock tensile strength, will near the shaft bottom, produce the crack in the stratum; Continue to inject the sand-carrying agent that contains propping agent, the crack is extended forward and is filled out with propping agent, thereby forms the sand packed fracture with certain geometrical dimension and flow conductivity in the stratum near the shaft bottom, to reach the purpose of increasing yield and injection.
The liquid that injects to the stratum in the waterfrac treatment process is called fracturing liquid, according to the effect of fracturing liquid different steps in fracturing process, can be divided into spearhead, sand-carrying agent and displacing liquid.Wherein, the effect of spearhead is fractured formation, causes the crack of certain geometrical dimension, so that sand-carrying agent subsequently enters; The effect of sand-carrying agent is propping agent to be carried enter crack to predetermined position, and wherein propping agent refers to after fracturing liquid is brought the crack into, the material in pressure release rear support crack, propping agent commonly used such as haydite, quartz sand etc.; The effect of displacing liquid is that sand-carrying agent is delivered to the predetermined position, and the whole sand-carrying agents in the pit shaft are replaced in the crack.
Existing fracturing liquid is mainly to be to use guar polymer frozen glue to take sand, generally will guarantee the pressure break scale, and the pressure break sand-carrying agent just must have certain viscosity (generally greater than 100mPa.s).Theoretical according to pressure break, the height in artificial fracturing crack is directly proportional with the net pressure in crack, i.e. h
f∝ P
Net/ Δ σ (D.M.Talbot and K.A.Hemke, " StimulationFracture Height Control Above Water or Depleted Zones ", paper SPE60318at the2000SPE Rocky Mountain Regional/Low Permeability Reservoirs Symposium held in Denver, CO, 12-15March2000); And the net pressure in crack is directly proportional with 1/3 power of of the fracturing fluid viscosity, namely
(X.Weng and V.Pandey, " Equilibrium Test-A Method for ClosurePressure Determination ", paper SPE/ISRM 78173 at the SPE/ISRM Rock MechanicsConference held in living, Texas, 20-23October2002).Because the fracture height that presses off is directly proportional with the viscosity of sand-carrying agent, of the fracturing fluid viscosity is higher, and fracture height is larger.For thin layer, fracture propagation is too high, penetrates reservoir, causes invalid pressure break or pressure break benefit to reduce; For end water reservoir, profit alternating layers and air water alternating layers, the too high easy communication water layer in crack causes water breakthrough, has had a strong impact on the effect of fracturing reform.Complicated such as Sebei Gas Field, qinghai reservoir air water relation, mutually, when conventional frac job, easily press off water layer between air water, gas-bearing formation is killed, cause the pressure break failure.
Therefore, in the fracturing process of thin reservoir, need the extended height in control fracturing crack.In order to control the extended height in crack, recent domestic has been developed by come-up or sinking diversion agent and has been controlled the technology that extend in one direction downward or upward in the crack.For example, Chinese patent application communique CN101864939A discloses a kind of crack to the method for downward-extension acid fracturing, the method utilizes high strength extremely-low density hollow glass micropearl as come-up crack diversion agent, the liquid that carries low-density hollow glass bead enters the crack, and (density is at 0.35g/cm owing to hollow glass micropearl density
3～0.55g/cm
3) (density is at 1.0g/cm with transport fluid density
3～1.2g/cm
3) poor larger, lower (the viscosity 10mPa.s～20mPa.s) of transport fluid viscosity, hollow glass micropearl floats to the top in crack on just can be quickly like this, because hollow glass micropearl is very thin, more than general 100～150 orders, so just can form very high blocking layer, stop fracturing fracture to extend upward, force fracturing fracture to downward-extension.
In addition, Chinese patent application communique CN101839124A discloses a kind of method of controlling oil-gas field reservoir fracturing fracture propagation, the method uses the fracturing liquid base fluid to carry modification haydite and solidifying agent, after the two enters the crack, under formation condition, react 40～90 minutes stroke high strength, without the perviousness barrier bed, excessively extend down into water layer thereby can slow down the crack.
Yet these two kinds come-ups and the forward methods that sink all will depend in liquid viscosity, density difference and the crack parameters such as flow velocity, and the operation easier in the practice of construction is large.
In addition, also have a kind of method of controlling fracture height by reducing operational discharge capacity in the reality, but owing to take the sand requirement, discharge capacity is crossed to hang down and will be caused fracture width narrow, and discharge capacity is low also can cause taking grittiness and descending of sand-carrying agent, thereby causes that sand plug causes pressing crack construction unsuccessfully.
Li Yongming etc. are at " the of the fracturing fluid research of fibrous ultralow density viscosifying agent " (" Drilling and completion fluids ", the 27th volume, the 2nd phase, in March, 2010) propose a kind of viscosifying agent concentration in and be 0.2% fibre-bearing fracturing liquid, wherein adopted linking agent to strengthen the fracturing liquid prop-carrying capacity.Yet, owing to behind linking agent and the viscosifying agent formation cross-linked network, still may cause the obstruction of pressure break band, thereby this fracturing liquid remains disadvantageous when being used for low discharge capacity fracturing process.
Therefore, need a kind of new fracturing liquid and fracturing process that provide, wherein this fracturing liquid has low viscosity, thereby can effectively control the extended height in crack in fracturing process under lower discharge capacity.
Summary of the invention
In view of this make the present invention, therefore, one object of the present invention is to provide a kind of new fracturing process, this fracturing process can be under lower discharge capacity the effective extended height in control fracturing crack, the requirement of fracture extended height when satisfying thin reservoir and having the hydrocarbon-bearing pool pressing crack construction of end water or middle water; Thus, another object of the present invention is to provide a kind of more low viscous fracturing liquid that has, replace the guar gum fracturing liquid, thereby in fracturing process, can reduce the net pressure that it produces fracturing fracture, the purpose of the extended height of achieve effective control fracturing fracture.
In order to realize this purpose, one aspect of the present invention provides a kind of aqueous fracturing fluid, described fracturing liquid enters in the formation fracture at fracturing process propping agent being carried, compared with prior art, can not use linking agent or even thickening material in the aqueous fracturing fluid of the present invention, thereby in low discharge capacity fracturing process, greatly reduce the possibility that blockage problem occurs; Wherein, comprise outstanding sand fiber in the described fracturing liquid, described outstanding sand fiber is selected from wetting ability high strength organic fibre or inorganic fibre, and described of the fracturing fluid viscosity is below the 10mPa.s, and wherein, described fracturing liquid does not comprise linking agent.The outstanding sand fiber of fracturing liquid utilization of the present invention forms tridimensional network and takes suspended prop, thereby can replace or reduce thickening material, reduce of the fracturing fluid viscosity, and reduce the net pressure that the fracturing liquid fracture produces, thereby in low discharge capacity fracturing technology the height in control fracturing crack effectively; On the other hand, the fibroplastic tridimensional network of outstanding sand of the present invention can satisfy the mechanics requirement of outstanding sand, thereby can improve fracturing effect.
On the other hand, when fracturing liquid of the present invention comprised thickening material, the amount of thickening material was preferably below 0.15 % by weight with respect to the fracturing liquid total amount, more preferably 0.08 % by weight～0.15 % by weight.
Preferably, in order further to reduce of the fracturing fluid viscosity, do not comprise thickening material in the fracturing liquid of the present invention.
For outstanding sand fiber, preferably, it has following performance perameter:
1. fibre tensile strength is: 20MPa～4000MPa;
2. fiber real density: 1.15g/cm
3～2.78g/cm
3
3. staple length: 3mm～15mm;
4. Fibre diameter: 8 μ m～500 μ m.
More preferably, the shape of outstanding sand fiber is forniciform, thereby can further improve the stability of fibrous reticular structure.
The hydrophilic fibre that satisfies above-mentioned performance perameter is selected from, and as inorganic fibre, can be at least a in glass fibre, carbon fiber, basalt fibre, ceramic fiber and the calcium polyphosphate fiber; As organic fibre, can be at least a in polypropylene fibre, polyacrylonitrile fibre, polyurethane fibre, polymeric amide, polyvinyl alcohol fiber, polyethylene fibre, trevira, acid fiber by polylactic and the polyparaphenylene's benzo-dioxazole fiber.
In one embodiment, based on the fresh water of 100 weight parts, aqueous fracturing fluid of the present invention contains outstanding sand fiber 0.3～1.0 weight part, and further, in the situation of selecting the bending fiber, the content of outstanding sand fiber is preferably 0.3～0.5 weight part.
In addition, can also comprise composition commonly used in the aqueous fracturing fluid of the present invention, such as fluid loss agent, emulsion splitter, cleanup additive and flow improver etc.In one embodiment, based on the fresh water of 100 weight parts, aqueous fracturing fluid of the present invention contains fluid loss agent 0.3～3.0 weight part, emulsion splitter 0.5～1.0 weight part, cleanup additive 0.5～1.0 weight part, flow improver 0.01～1.0 weight part.
Another aspect of the present invention provides a kind of fracturing process, described fracturing process has used the fracturing liquid that comprises above-mentioned outstanding sand fiber as sand-carrying agent, utilize outstanding sand fiber to form tridimensional network and take suspended prop, thereby can significantly reduce the viscosity of sand-carrying agent, effective control fracturing fracture propagation height under lower discharge capacity.
Wherein, the feature of described of the fracturing fluid composition and outstanding sand fiber is as indicated above.Fracturing process of the present invention comprises and injects acid solution, injects spearhead, injects sand-carrying agent and with stages such as slippery water replacements.
In one embodiment, the parameter that fracturing process of the present invention injects sand-carrying agent is as follows: use 50～200 cubic metres sand-carrying agent, inject the stratum with 2.0～3.5 cubic meters per minute discharge capacities, propping agent is carried press off supporting crack in the crack.
In another embodiment, the parameter that fracturing process of the present invention injects spearhead is as follows: use 20～200 cubic metres spearhead, inject the stratum with the discharge capacity of 1.5～3.0 cubic meters per minute and crack.
In another embodiment, fracturing process of the present invention at first injects acid solution to remove the pollution of borehole, and wherein, the parameter that acid solution is injected is as follows: use 5～20 cubic metres acid solution, inject the stratum with 0.5～1.5 cubic meters per minute discharge capacity.
In another embodiment, the consumption of slippery water displacing liquid is equivalent to the volume of operating tool string in the fracturing process of the present invention.
As hereinafter disclosing, fracturing liquid and fracturing process that the present invention is used for control fracture propagation height have following beneficial effect: with the outstanding sand facies ratio of conventional pressure break high viscosity, in fracturing liquid, form the outstanding sand of tridimensional network by outstanding sand fiber, can replace conventional fracturing liquid to rely on its high viscosity to hang sand, thereby can effectively reduce of the fracturing fluid viscosity, the extension in the vertical of control waterfrac treatment man-made fracture, and then effectively control the height of man-made fracture, press off water layer when preventing gas (oil) water alternating layers hydrocarbon-bearing pool pressure break, gas (oil) lamination is dead, cause the pressure break failure; Simultaneously, outstanding sand fiber forms tridimensional network and can stably hang sand in fracturing liquid, thereby for the fracturing reform of thin reservoir, and the present invention can be with Crack Control in reservoir, thus the economic benefit of raising fracturing reform.
Description of drawings
Fig. 1 shows the lab diagram of the outstanding sand situation of fiber of the present invention.
Fig. 2 shows the graphic representation of the viscosity of the outstanding sand liquid of fiber of the present invention.
Fig. 3 shows the graph of a relation of Sebei Gas Field part gas well gas water layer.
Fig. 4 shows the synoptic diagram of the fracturing string of A well.
Fig. 5 shows the graphic representation of the pressing crack construction of control fracture propagation height in the A well.
Fig. 6 shows the graphic representation that fracture height is explained in the well temperature log of A well.
Embodiment
Specifically describe the present invention below with reference to drawings and Examples.Those skilled in the art will be appreciated that by following description embodiment of the present invention is just implemented illustrative examples of the present invention, and it can not be used for limiting purpose of the present invention.Except as otherwise noted, the unit of hereinafter mentioning " part " all refers to " weight part ", and percentage ratio is weight percentage; The weight percentage of each composition (or percentage ratio) is all take of the fracturing fluid gross weight as benchmark in the fracturing liquid as herein described.
Wherein, the term among the present invention " viscosity " refers to use the acidproof rotational viscosimeter of RV-20 type (German HAAKE company), is 170s in shearing rate
-1The viscosity number that records down.
It is 1～5 cubic meters per minute that term used herein " lower discharge capacity " refers to inject of the fracturing fluid amount, is preferably 1.5～3.5 cubic meters per minute.
Term mentioned herein " thickening material " refers to water-soluble polymers natural or synthetic, such as materials such as guar gum (such as hydroxypropylguar gum, carboxymethyl guar gum or hydroxypropyl carboxy methyl guar gum) or polypropylene amines.
Fracturing liquid of the present invention at first is described.As mentioned above, the purpose of this invention is to provide a kind of fracturing liquid that comprises outstanding sand fiber, described fracturing liquid is used as sand-carrying agent in fracturing technology, and can in formation fracture, form tridimensional network and take suspended prop, to replace full-bodied guar gum to hang sand, thereby can be with of the fracturing fluid reduced viscosity to 10mPa.s, this viscosity number is conducive to the height in control fracturing crack.For the viscosity of control fracturing liquid better, do not comprise the linking agent that is generally used in the guar gum fracturing liquid in the fracturing liquid of the present invention.
Fracturing liquid of the present invention is generally aqueous fracturing fluid, preferably, does not contain just like thickening materials such as guar gums in the described fracturing liquid, so that of the fracturing fluid viscosity satisfies demand of the present invention better.
Air inclusion component not in the fracturing liquid of the present invention is because air inclusion can weaken the intensity of fiber and then the outstanding grittiness energy of impact in the fracturing liquid.
Because of the fracturing fluid viscosity is lower, thereby the outstanding sand fiber that plays outstanding sand effect in the fracturing liquid of the present invention need to have following character: outstanding sand fiber is easy to be dispersed in the fracturing liquid, is easy to form tridimensional network and has certain intensity is taken sand to satisfy waterfrac treatment requirement.
Particularly, the outstanding sand fiber in the sand-carrying agent be can be in aqueous fracturing fluid homodisperse wetting ability high strength organic fibre or inorganic fibre.Wherein, the wetting ability of fiber has no particular limits, and gets final product as long as its character can satisfy the requirement of " surface is easy to water-wet, and fiber itself disperses easily " in water.Thus, those skilled in the art can select the suitable hydrophilic fibre for the present invention by foregoing description.
In addition, in the present invention, the intensity of outstanding sand fiber thinks that in tensile strength the tensile strength of 20MPa～4000MPa satisfies requirement of the present invention.
When the outstanding sand fiber dispersion of this type of wetting ability is in fracturing liquid, will in fracturing liquid, forms tridimensional network, and satisfy the requirement that sand is taken in waterfrac treatment.And the viscosity of the sand-carrying agent that so forms is basic suitable with clear water, and its viscosity ratio is conventional takes little 2 orders of magnitude of viscosity of the sand-carrying agent of sand by viscosity, therefore, uses this fracturing liquid, is hanging down the discharge capacity fracturing and can effectively control the man-made fracture height of waterfrac treatment.
Outstanding sand fiber also has following character:
1. fibre tensile strength is: 20MPa～4000MPa;
2. fiber real density: 1.10g/cm
3～2.78g/cm
3
3. staple length: 3mm～15mm;
4. Fibre diameter: 8 μ m～500 μ m.
Herein, staple length refers to the straight length that fiber is measured in stretching rear its maximum length, and the outstanding sand network of monolithic devices refers to the integrated reticulated structure body that homodisperse outstanding sand fiber forms in whole fracturing liquids by linking each other.
Preferably, the shape of outstanding sand fiber of the present invention is forniciform.The inventor finds, with linear pattern Fiber Phase ratio commonly used, the easier formation reticulated structure that links each other of bending fiber of the present invention, thereby when fiber was evenly dispersed in the aqueous fracturing fluid, it can form stable outstanding sand network everywhere at fracturing liquid and take suspended prop.When selecting the outstanding sand fiber of bending, the amount of outstanding sand fiber can greatly reduce among the present invention, and in one embodiment, with respect to 100 parts fresh water, the content of outstanding sand fiber is 0.3～0.5 part.
Wherein, inorganic fibre can be at least a in glass fibre, carbon fiber, basalt fibre, ceramic fiber and the calcium polyphosphate fiber; Organic fibre can be at least a in polypropylene fibre, polyacrylonitrile fibre, polyurethane fibre, polymeric amide, polyvinyl alcohol fiber, polyethylene fibre, trevira, acid fiber by polylactic and the polyparaphenylene's benzo-dioxazole fiber.
The inventor finds by research, by selecting fiber with above-mentioned performance, at first, because its wetting ability, can be evenly dispersed in fracturing liquid everywhere in the aqueous fracturing fluid time in dispersion, forms the monolithic devices three-dimensional network; Secondly, because fiber has specific intensity, thereby the three-dimensional network of its formation can stand the pressure that propping agent sinks, thereby slows down or suppress the speed of proppants settle down; Moreover when being shaped as preferred bending, fiber can link the stability that guarantees three-dimensional network each other, can use the fiber of small amount can reach the needs that hang sand; Thus, fracturing liquid of the present invention can reach required viscosity, thereby can carry out fracturing operation under lower discharge capacity when reach outstanding sand requirement, and the height in control fracturing crack effectively.
In order to help outstanding sand, can also comprise a small amount of thickening material and/or flow improver in the fracturing liquid of the present invention, wherein, when fracturing liquid is used as sand-carrying agent, thickening material can be guar gum or such as high molecular weight water-soluble linear polymers such as polyacrylamides, flow improver is such as being the tensio-active agents such as cetyl trimethylammonium bromide, palmityl trimethyl ammonium chloride, trimethyl-glycine.
Yet at the fracturing liquid that other stages of fracturing technology use, in spearhead and displacing liquid, as known in the art, guar gum or polyacrylamide, polyvinyl alcohol etc. also can be used as flow improver.
In one embodiment, the fracturing liquid as transporting agent has following component: fresh water is 100 parts; 0.3～1.0 part of outstanding sand fiber; 0.3～3.0 part of fluid loss agent; 0.5～1.0 part of emulsion splitter; 0.5～1.0 part of cleanup additive; 0.08～0.18 part of thickening material; 0.1～1.0 part of flow improver.Wherein, the fineness of fluid loss agent can be 60～200 orders.
Wherein, fracturing liquid can carry propping agent with ratio commonly used in this area, and for example propping agent is in 5 volume %～50 volume % (60kg/m again
3～780kg/m
3) take sand than mixing with fracturing liquid.Propping agent of the present invention can be the propping agent form commonly used of this area, such as the haydite of various particle diameters, pressure break with quartz sand etc.; The fineness of propping agent can be 20～40 orders, 30～50 orders, 40～60 orders or 50 orders/70 orders.
In addition, above-mentioned fluid loss agent can be one or more the mixture in calcium carbonate powders, starch, powder pottery, fine silt, the resin; Emulsion splitter can be condensation compound of alkyl phenol and epoxy ethane and cats product; Cleanup additive can be fluorochemical surfactant; Selecting of thickening material and flow improver is as indicated above.
Below will specify fracturing process of the present invention.As indicated above, fracturing process of the present invention mainly is, use comprises the fracturing liquid of above-mentioned outstanding sand fiber as sand-carrying agent, in formation fracture, form tridimensional network and take suspended prop, thereby can significantly reduce the viscosity of sand-carrying agent, under lower discharge capacity, can not cause sand plug yet, thus the extended height in effective control fracturing crack.
Hydraulic fracturing method of the present invention can be used for the waterfrac treatment transformation of the reservoirs such as petroclastic rock, carbonatite, volcanic rock or shale.And fracturing process of the present invention not only can be used for the pressure break of straight well, can also be used for inclined shaft, fractured horizontal well transformation.
Fracturing process of the present invention mainly comprises three phases.Fs is to use acid solution to remove the obstruction of nearly well band, reduces the parting pressure of rock, and then is conducive to pressing crack construction.Subordinate phase uses spearhead to press off the stratum, forms crack of certain scale.Phase III uses sand-carrying agent to carry propping agent and fills supporting crack.
In addition, fracturing process of the present invention can also after being filled into propping agent in the crack, use the slippery water displacing liquid to replace.
Thereby in one embodiment, fracturing process of the present invention can may further comprise the steps:
(1) uses 5～20 cubic metres acid solution, inject the stratum with 0.5～1.5 cubic meters per minute discharge capacity, remove the pollution of borehole;
(2) use 20～200 cubic metres of spearheads, inject the stratum with 1.5～3.0 cubic meters per minute discharge capacities and crack;
(3) use 50～200 cubic metre of 2.0～3.5 cubic meters per minute discharge capacity infusion sand-carrying agent to enter the stratum, propping agent is carried press off supporting crack in the crack, form the man-made fracture with certain flow conductivity at reservoir;
(4) use slippery water to replace (consumption is equivalent to the volume of operating tool string).
Wherein, the sand-carrying agent that uses in the fracturing process has composition mentioned above.Acid solution of the present invention, spearhead and slippery water displacing liquid can have the common composition in this area.For example, as an example, acid solution of the present invention can have following component: 100 parts of fresh water; 30～50 parts of 31% technical hydrochloric acids; 2～10 parts of 40% industrial hydrofluoric acids; 0.8～3.5 part of inhibiter; 0.2～1.5 part of Fe stabilizer; 0.2～1.5 part of clay stabilizer.
Wherein, the inhibiter in the above-mentioned acid solution can be the commercial goods KMS-6 inhibiter of Beijing KeMaiShi Oil Field Chemical regent Technology Co., Ltd; Fe stabilizer can be the commercial goods KMS-7 Fe stabilizer of Beijing KeMaiShi Oil Field Chemical regent Technology Co., Ltd; Clay stabilizer can be the quaternaries cation polymkeric substance.
As an example, spearhead of the present invention can have following component: 100 parts of fresh water; 0.5～6.0 part of fluid loss agent, 0.2～4.0 part of clay stabilizer; 0.5～1.0 part of emulsion splitter; 0.5～1.0 part of cleanup additive; 0.01～1.0 part of flow improver; Wherein the fineness of fluid loss agent is 60～200 orders.
In addition, as an example, the slippery water displacing liquid can have following component: fresh water is 100 parts; 0.5～1 part of cleanup additive; 0.01～1.0 part of flow improver.
Wherein, the clay stabilizer that uses in the spearhead can be Repone K, ammonium chloride or dimethyl diallyl ammonium chloride homopolymer.Selecting as mentioned above of fluid loss agent in spearhead and the displacing liquid, emulsion splitter, cleanup additive and flow improver etc.
In addition, should be understood that the content of not describing in detail in the explanation of above-mentioned fracturing liquid and fracturing process all is Common Parameters that those skilled in the art expect easily, therefore can omit detailed description thereof.
Embodiment
Embodiment 1: the effect of outstanding sand fiber experiment under the room temperature
At room temperature, disposed the fracturing liquid with following composition: fresh water 200ml; Ceramic fiber (length 10mm, diameter 15 μ m, tensile strength 3000Mpa; The Beijing KeMaiShi Oil Field Chemical regent Technology Co., Ltd) 1.6g; 200 order degradable starch (fluid loss agent) 3g; Fluorochemical surfactant (the new chemical industry of military China continues for cleanup additive, FC203) 1g; Cetyl trimethylammonium bromide (commercially available) 1g.
This fracturing liquid is placed under the room temperature, and recording its viscosity after 15 minutes is 9mPa.s, and visual observation.As shown in Figure 1, observe in this experiment the fracturing liquid sample that comprises outstanding sand fiber and obtained excellent outstanding sand effect.
Comparative example 1: the conventional pressure break of gas well
At first, select gas well A to carry out fracturing process of the present invention in Caidamu Basin Qinghai Oil Field Sebei Gas Field, the geographical conditions of Sebei Gas Field are as described in the embodiment 2 hereinafter.At first the offset well of this gas well A uses conventional guar gum fracturing liquid (guar concentrations is 0.45 % by weight) to carry out pressure break under low discharge capacity, and of the fracturing fluid viscosity is about 15mPa.s, and fracturing effect is undesirable: on average produce tolerance 3.5 * 10 daily
4m
3, water yield 5m
3
Embodiment 2: low discharge capacity pressure break of the present invention
As shown in Figure 3, Caidamu Basin Sebei Gas Field air water ATM layer relationsATM is complicated, there are Di Shui, limit water and middle water, for air water alternating layers, end water apart from gas-bearing formation near or air water layer at a distance of 10m with interior reservoir, use conventional fracture technology, because crack extension in the vertical, can will press off at a distance of nearer water layer, cause and link up water layer and cause gas-bearing formation to be subject to water logging, thereby cause a large amount of water outlets of gas well, pressure break failure (shown in comparative example 1 like that).
Fig. 4 shows the fracturing string figure of A well.As shown in Figure 4, this gas well gas layer well section is 1700.2m～1701.6m, 1703.8m～1707.2m, 1708.8m～1712.8m and 1716.1m～1719.9m, and the accumulative total net thickness is 12.6m, and span is 19.7m.Wherein 9.4m place in payzone top exists a plurality of air waters with layer and gassiness water layer, and also there is the gassiness water layer in 12.0m place, payzone bottom.Provided the concrete physical property of A well fractured interval in the following table 1; Table 2 has provided master data and the strength check data of oil pipe.
Table 1
Consider that gas-bearing formation has up and down gassiness water layer and water layer, and water layer apart from gas-bearing formation distance all about 10m, this well adopts conventional fracturing technology to be difficult to control the longitudinal extension of man-made fracture, thereby causes fracture propagation to the gassiness water layer of gas-bearing formation upper and lower.
Thereby, having adopted the fracturing liquid that comprises outstanding sand fiber in the present embodiment, this fracturing liquid has lower viscosity, in conjunction with fracturing process of the present invention, uses lower discharge capacity, thereby can be with Crack Control in 1695m～1725m.Fracturing liquid as sand-carrying agent in the present embodiment has used following outstanding sand fiber: ceramic fiber (the same), concentration is 0.5 volume % (about 0.8 % by weight), of the fracturing fluid viscosity is 9mPa.s, and it satisfies requirement of the present invention (being that 10mPa.s is following).
The fracturing process that adopts in the present embodiment is as follows:
1, fracturing string
1. adopt Φ 73mm external upset combination oil pipe injection mode to construct oil pipe depth of setting 1630m (seeing Fig. 4).
2. construct according to design calculation Selection and Constitute oil pipe, oil pipe master data and tensile strength are checked and are seen Table 2.
Table 2
2, fracturing process
Fig. 5 shows the hydraulic fracture operating curve of present embodiment.Particularly, fracturing process of the present invention comprises:
1. use 20 cubic metres of spearheads, inject the stratum with 2.0～2.2 cubic meters per minute discharge capacities and crack;
2. use 90 cubic metres of sand-carrying agents, with 2.2～2.8 cubic meters per minute discharge capacity infusions, take sand and carry out pressing crack construction than for being segmented into 5%～35%, add 20 cubic metres of Lanzhou pressure break quartz sands (40～60 order);
3. use 5 cubic metres of slippery water, replace with 2.8 cubic meters per minute discharge capacities.
4. termination of pumping, pressure measurement is fallen.
Wherein, the component and the content that adopt in the above-mentioned fracturing liquid are:
Each components by weight of spearhead is: 100 parts of fresh water; 1.5 parts of 200 order degradable starchs (fluid loss agent, W-Gum, commercially available); 3.0 parts in Repone K (clay stabilizer, commercially available); 0.5 part of fluorochemical surfactant (cleanup additive, the same); 0.5 part of cetyl trimethylammonium bromide (flow improver, the same).
Each components by weight of sand-carrying agent is: 100 parts of fresh water; 0.8 part of ceramic fiber (the same); 1.5 parts of 200 order degradable starchs (fluid loss agent, the same); 0.5 part of fluorochemical surfactant (cleanup additive, the same); 0.5 part of cetyl trimethylammonium bromide (flow improver, the same).
Each components by weight of slippery water displacing liquid is: fresh water is 100 parts; 0.5 part of fluorochemical surfactant (cleanup additive, the same); 0.5 part of cetyl trimethylammonium bromide (flow improver, the same).
Propping agent: 40～60 order pressure break Lanzhou quartz sands.
3, pressing crack construction Crack Monitoring data
Carry out basic well temperature is measured before pressing crack construction, pressing crack construction finishes to carry out a well temperature log in 1 hour again.Fig. 6 shows the result of temperature survey, wherein with twice well temperature curve plotting on same figure.Pressing crack construction forms three cracks as seen from Figure 6, and the seam height is respectively 2.5m, 7.5m, and 9m always stitches high 23.5m, and the crack all is controlled in 1700m～1725m interval water layer about not linking up.
By contrast, adopt fracturing process of the present invention before, for the valve of 5mm, the daily output tolerance 2.53 * 10
4m
3, water yield per day 0.32m
3Behind fracturing reform, produce equally daily output tolerance 5.72 * 10 with the 5mm valve
4m
3, water yield per day 0.41m
3
This shows, adopt fracturing liquid of the present invention and fracturing process, since decrease the viscosity of fracturing liquid itself, thereby effectively the control fracturing crack at extended height longitudinally, can not press off at a distance of nearer water layer, thus for thin reservoir, particularly for air water alternating layers, end water apart from gas-bearing formation near or air water layer at a distance of 10m with interior reservoir, realize excellent fracturing effect, reached the purpose of fracturing yield increasing.
Claims (10)
1. waterfrac treatment aqueous fracturing fluid, described fracturing liquid is used for carrying propping agent, it is characterized in that, described fracturing liquid comprises outstanding sand fiber, described outstanding sand fiber is selected from wetting ability high strength organic fibre or inorganic fibre, and described of the fracturing fluid viscosity is below the 10mPa.s, and wherein, described fracturing liquid does not comprise linking agent.
2. fracturing liquid as claimed in claim 1, wherein, described fracturing liquid does not comprise thickening material.
3. fracturing liquid as claimed in claim 1, wherein, described outstanding sand fiber is forniciform.
4. fracturing liquid as claimed in claim 1, wherein, described outstanding sand fiber has following performance perameter:
1. fibre tensile strength is: 20MPa～4000MPa;
2. fiber real density: 1.10g/cm
3～2.78g/cm
3
3. staple length: 3mm～15mm;
4. Fibre diameter: 8 μ m～500 μ m.
5. such as each described fracturing liquid in the claim 1～4, wherein, described inorganic fibre is selected from least a in glass fibre, carbon fiber, basalt fibre, ceramic fiber and the calcium polyphosphate fiber; Described organic fibre is selected from least a in polypropylene fibre, polyacrylonitrile fibre, polyurethane fibre, polymeric amide, polyvinyl alcohol fiber, polyethylene fibre, trevira, acid fiber by polylactic and the polyparaphenylene's benzo-dioxazole fiber.
6. such as each described fracturing liquid in the claim 1～5, wherein, based on the fresh water of 100 weight parts, described fracturing liquid contains the outstanding sand fiber of 0.3～1.0 weight part.
7. a hydraulic fracturing method is characterized in that, described fracturing process right to use requires in 1～6 each described fracturing liquid as sand-carrying agent, presses off in the crack thereby propping agent carried.
8. method as claimed in claim 7, wherein, the injection parameter of sand-carrying agent is: 50～200 cubic metres, injection speed is 2.0～3.5 cubic meters per minute.
9. such as claim 6 or 7 described methods, wherein, described method also comprises, before injecting sand-carrying agent, uses 20～200 cubic metres spearhead, injects formation fracture with the discharge capacity of 1.5～3.0 cubic meters per minute.
10. such as each described method in the claim 7～9, wherein, described method also comprises, before injecting spearhead, injects the pollution that acid solution is removed borehole, and the acid solution injection parameter is: 50～20 cubic metres, injection speed is 0.5～1.5 cubic meters per minute.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210392429.0A CN102925133B (en) | 2012-10-16 | 2012-10-16 | Fracturing fluid and fracturing method for controlling fracture extension height |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210392429.0A CN102925133B (en) | 2012-10-16 | 2012-10-16 | Fracturing fluid and fracturing method for controlling fracture extension height |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN102925133A true CN102925133A (en) | 2013-02-13 |
| CN102925133B CN102925133B (en) | 2014-11-26 |
Family
ID=47640067
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201210392429.0A Active CN102925133B (en) | 2012-10-16 | 2012-10-16 | Fracturing fluid and fracturing method for controlling fracture extension height |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN102925133B (en) |
Cited By (34)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103694976A (en) * | 2013-12-18 | 2014-04-02 | 四川省博仁达石油科技有限公司 | Fiber temporary plugging agent for acidizing and fracturing |
| CN103725277A (en) * | 2013-12-18 | 2014-04-16 | 四川省博仁达石油科技有限公司 | Fibre compound temporary plugging agent |
| CN104212436A (en) * | 2013-06-05 | 2014-12-17 | 中国石油天然气股份有限公司 | Fracturing fluid for mixed water fracturing |
| CN104533375A (en) * | 2014-12-26 | 2015-04-22 | 中国石油天然气股份有限公司 | Fracturing transformation method for natural fractured reservoir |
| CN104712299A (en) * | 2013-12-11 | 2015-06-17 | 中国石油天然气股份有限公司 | Design method suitable for water control and gas increase fracturing of gas well |
| CN104946229A (en) * | 2015-05-29 | 2015-09-30 | 中国石油天然气股份有限公司 | Composite synergist for fiber fracturing fluid and preparation method and use method thereof |
| CN104962275A (en) * | 2015-05-29 | 2015-10-07 | 中国石油天然气股份有限公司 | Fiber active water fracturing fluid for tight reservoir reconstruction and application method thereof |
| CN104974739A (en) * | 2015-07-10 | 2015-10-14 | 四川大学 | Cellulose blended modified polyvinyl alcohol fracturing fluid and preparation method thereof |
| CN105143393A (en) * | 2013-03-15 | 2015-12-09 | 普拉德研究及开发股份有限公司 | Compositions and methods for increasing fracture conductivity |
| CN104406768B (en) * | 2014-12-02 | 2017-01-25 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Fracture flow simulation experiment device and method for fiber blend support agent |
| CN106833595A (en) * | 2017-03-13 | 2017-06-13 | 河南理工大学 | A kind of multi-solvent combination fracturing liquid and coal bed gas well pressing crack construction technique |
| CN106958438A (en) * | 2017-02-20 | 2017-07-18 | 中国石油化工股份有限公司 | A kind of polymer flooding blocks the method for removing blockage of well |
| CN107287674A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of soluble fine-denier PVA fibers and application thereof |
| CN107286916A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of oil-gas field fracturing liquid containing PVA, PVA fiber, oil gas field well cementation agent and oil-gas field fracturing diverting agent |
| CN107287669A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of alkaline-resisting temperature resistance PVA fibers and application thereof |
| CN107287673A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of soluble thick denier PVA fibers and application thereof |
| CN107286922A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of oil-gas field fracturing liquid containing PVA fibers, oil gas field well cementation agent and oil-gas field fracturing diverting agent |
| CN107503725A (en) * | 2017-10-10 | 2017-12-22 | 西南石油大学 | A kind of method for controlling hydraulic fracture extended height |
| CN107558980A (en) * | 2017-07-18 | 2018-01-09 | 中国石油天然气股份有限公司 | Low-density temporary plugging crack length-extension-restraining fracturing method |
| CN104405360B (en) * | 2014-10-27 | 2018-02-27 | 中石化胜利油田分公司采油工艺研究院 | A kind of fracturing process for improving fracturing fluid solid-carrying performance |
| CN107780916A (en) * | 2017-09-21 | 2018-03-09 | 成都理工大学 | High acid fracturing method is stitched in a kind of control suitable for Deep Carbonate Rocks |
| CN108660540A (en) * | 2018-04-12 | 2018-10-16 | 中国石油天然气股份有限公司 | Reticular fiber for fracturing and preparation method thereof |
| CN108732010A (en) * | 2017-04-24 | 2018-11-02 | 中国石油天然气股份有限公司 | Simulation and evaluation device and method for fracturing crack |
| CN109915101A (en) * | 2017-12-13 | 2019-06-21 | 北京华油油气技术开发有限公司 | A kind of full fracture guide fracturing technology |
| CN109958427A (en) * | 2017-12-22 | 2019-07-02 | 中国石油化工股份有限公司 | A kind of improvement effectively supports the fracturing process of section |
| CN110793861A (en) * | 2019-11-01 | 2020-02-14 | 中国石油大学(北京) | Test method and device for determining hydraulic fracturing gravel penetration discharge capacity of conglomerate test piece |
| CN112228031A (en) * | 2020-10-14 | 2021-01-15 | 中国石油天然气股份有限公司 | Fracturing method for controlling extending direction of crack |
| CN112431569A (en) * | 2020-10-15 | 2021-03-02 | 中国石油天然气股份有限公司 | Method for preventing crack from extending upwards, high-molecular plugging material and preparation method thereof |
| CN112443305A (en) * | 2019-09-04 | 2021-03-05 | 中国石油化工股份有限公司 | Horizontal well fracturing method for promoting high fracture extension through twice acid injection and temporary plugging among clusters |
| CN113513298A (en) * | 2021-08-04 | 2021-10-19 | 广州海洋地质调查局 | Hot dry rock branch well same-well synchronous injection-production method and injection-production device |
| CN114458275A (en) * | 2021-12-30 | 2022-05-10 | 中国石油化工股份有限公司 | Multilayer small sand body comprehensive fracturing method for underwater diversion river sediment microphase |
| CN115434659A (en) * | 2021-06-02 | 2022-12-06 | 中国石油天然气集团有限公司 | Process method for deep fixed-point feeding of blocking agent for high-permeability reservoir |
| CN116218486A (en) * | 2021-12-03 | 2023-06-06 | 中国石油天然气集团有限公司 | Degradable sand carrying agent for drilling and completion fluid and preparation method thereof |
| CN116498287A (en) * | 2023-06-29 | 2023-07-28 | 四川圣诺油气工程技术服务有限公司 | Height control method for sand fracturing artificial cracks |
Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20080093073A1 (en) * | 2006-10-24 | 2008-04-24 | Oscar Bustos | Degradable Material Assisted Diversion |
| CN102071919A (en) * | 2010-12-28 | 2011-05-25 | 中国石油大学(华东) | Oil-gas well fiber assisted water control fracturing method |
-
2012
- 2012-10-16 CN CN201210392429.0A patent/CN102925133B/en active Active
Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20080093073A1 (en) * | 2006-10-24 | 2008-04-24 | Oscar Bustos | Degradable Material Assisted Diversion |
| CN102071919A (en) * | 2010-12-28 | 2011-05-25 | 中国石油大学(华东) | Oil-gas well fiber assisted water control fracturing method |
Cited By (53)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US10526531B2 (en) | 2013-03-15 | 2020-01-07 | Schlumberger Technology Corporation | Compositions and methods for increasing fracture conductivity |
| CN105143393A (en) * | 2013-03-15 | 2015-12-09 | 普拉德研究及开发股份有限公司 | Compositions and methods for increasing fracture conductivity |
| CN111456700A (en) * | 2013-03-15 | 2020-07-28 | 斯伦贝谢控股有限公司 | Method of treating a subterranean formation |
| CN104212436A (en) * | 2013-06-05 | 2014-12-17 | 中国石油天然气股份有限公司 | Fracturing fluid for mixed water fracturing |
| CN104712299B (en) * | 2013-12-11 | 2017-09-01 | 中国石油天然气股份有限公司 | Design method suitable for water control and gas increase fracturing of gas well |
| CN104712299A (en) * | 2013-12-11 | 2015-06-17 | 中国石油天然气股份有限公司 | Design method suitable for water control and gas increase fracturing of gas well |
| CN103725277B (en) * | 2013-12-18 | 2016-03-16 | 四川省博仁达石油科技有限公司 | A kind of fiber composite temporary plugging agent |
| CN103694976A (en) * | 2013-12-18 | 2014-04-02 | 四川省博仁达石油科技有限公司 | Fiber temporary plugging agent for acidizing and fracturing |
| CN103725277A (en) * | 2013-12-18 | 2014-04-16 | 四川省博仁达石油科技有限公司 | Fibre compound temporary plugging agent |
| CN104405360B (en) * | 2014-10-27 | 2018-02-27 | 中石化胜利油田分公司采油工艺研究院 | A kind of fracturing process for improving fracturing fluid solid-carrying performance |
| CN104406768B (en) * | 2014-12-02 | 2017-01-25 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Fracture flow simulation experiment device and method for fiber blend support agent |
| CN104533375A (en) * | 2014-12-26 | 2015-04-22 | 中国石油天然气股份有限公司 | Fracturing transformation method for natural fractured reservoir |
| CN104946229A (en) * | 2015-05-29 | 2015-09-30 | 中国石油天然气股份有限公司 | Composite synergist for fiber fracturing fluid and preparation method and use method thereof |
| CN104962275A (en) * | 2015-05-29 | 2015-10-07 | 中国石油天然气股份有限公司 | Fiber active water fracturing fluid for tight reservoir reconstruction and application method thereof |
| CN104946229B (en) * | 2015-05-29 | 2018-12-25 | 中国石油天然气股份有限公司 | Composite synergist for fiber fracturing fluid and preparation method and use method thereof |
| CN104962275B (en) * | 2015-05-29 | 2017-12-05 | 中国石油天然气股份有限公司 | Fiber active water fracturing fluid for tight reservoir reconstruction and application method thereof |
| CN104974739A (en) * | 2015-07-10 | 2015-10-14 | 四川大学 | Cellulose blended modified polyvinyl alcohol fracturing fluid and preparation method thereof |
| CN107286922A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of oil-gas field fracturing liquid containing PVA fibers, oil gas field well cementation agent and oil-gas field fracturing diverting agent |
| CN107287673A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of soluble thick denier PVA fibers and application thereof |
| CN107287669A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of alkaline-resisting temperature resistance PVA fibers and application thereof |
| CN107286916A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of oil-gas field fracturing liquid containing PVA, PVA fiber, oil gas field well cementation agent and oil-gas field fracturing diverting agent |
| CN107287674A (en) * | 2016-04-12 | 2017-10-24 | 中国石油化工集团公司 | A kind of soluble fine-denier PVA fibers and application thereof |
| CN107287673B (en) * | 2016-04-12 | 2020-07-03 | 中国石油化工集团公司 | Soluble coarse denier PVA fiber and application thereof |
| CN106958438A (en) * | 2017-02-20 | 2017-07-18 | 中国石油化工股份有限公司 | A kind of polymer flooding blocks the method for removing blockage of well |
| CN106833595B (en) * | 2017-03-13 | 2021-12-28 | 河南理工大学 | Multi-solvent combined fracturing fluid and fracturing construction process of coal-bed gas well |
| CN106833595A (en) * | 2017-03-13 | 2017-06-13 | 河南理工大学 | A kind of multi-solvent combination fracturing liquid and coal bed gas well pressing crack construction technique |
| CN108732010A (en) * | 2017-04-24 | 2018-11-02 | 中国石油天然气股份有限公司 | Simulation and evaluation device and method for fracturing crack |
| CN108732010B (en) * | 2017-04-24 | 2021-06-01 | 中国石油天然气股份有限公司 | Simulation and evaluation device and method for fracturing crack |
| CN107558980B (en) * | 2017-07-18 | 2020-05-08 | 中国石油天然气股份有限公司 | Low-density temporary plugging crack length-extension-restraining fracturing method |
| CN107558980A (en) * | 2017-07-18 | 2018-01-09 | 中国石油天然气股份有限公司 | Low-density temporary plugging crack length-extension-restraining fracturing method |
| CN107780916A (en) * | 2017-09-21 | 2018-03-09 | 成都理工大学 | High acid fracturing method is stitched in a kind of control suitable for Deep Carbonate Rocks |
| CN107780916B (en) * | 2017-09-21 | 2019-06-07 | 成都理工大学 | A kind of high acid fracturing method of control seam suitable for Deep Carbonate Rocks |
| CN107503725A (en) * | 2017-10-10 | 2017-12-22 | 西南石油大学 | A kind of method for controlling hydraulic fracture extended height |
| CN109915101A (en) * | 2017-12-13 | 2019-06-21 | 北京华油油气技术开发有限公司 | A kind of full fracture guide fracturing technology |
| CN109958427A (en) * | 2017-12-22 | 2019-07-02 | 中国石油化工股份有限公司 | A kind of improvement effectively supports the fracturing process of section |
| CN108660540B (en) * | 2018-04-12 | 2021-01-29 | 中国石油天然气股份有限公司 | Reticular fiber for fracturing and preparation method thereof |
| CN108660540A (en) * | 2018-04-12 | 2018-10-16 | 中国石油天然气股份有限公司 | Reticular fiber for fracturing and preparation method thereof |
| CN112443305A (en) * | 2019-09-04 | 2021-03-05 | 中国石油化工股份有限公司 | Horizontal well fracturing method for promoting high fracture extension through twice acid injection and temporary plugging among clusters |
| CN112443305B (en) * | 2019-09-04 | 2022-07-05 | 中国石油化工股份有限公司 | Horizontal well fracturing method for promoting high fracture extension through twice acid injection and temporary plugging among clusters |
| CN110793861B (en) * | 2019-11-01 | 2020-10-13 | 中国石油大学(北京) | Test method and device for determining hydraulic fracturing gravel penetration discharge capacity of conglomerate test piece |
| CN110793861A (en) * | 2019-11-01 | 2020-02-14 | 中国石油大学(北京) | Test method and device for determining hydraulic fracturing gravel penetration discharge capacity of conglomerate test piece |
| CN112228031A (en) * | 2020-10-14 | 2021-01-15 | 中国石油天然气股份有限公司 | Fracturing method for controlling extending direction of crack |
| CN112431569A (en) * | 2020-10-15 | 2021-03-02 | 中国石油天然气股份有限公司 | Method for preventing crack from extending upwards, high-molecular plugging material and preparation method thereof |
| CN112431569B (en) * | 2020-10-15 | 2022-12-02 | 中国石油天然气股份有限公司 | Method for preventing crack from extending upwards, high-molecular plugging material and preparation method thereof |
| CN115434659A (en) * | 2021-06-02 | 2022-12-06 | 中国石油天然气集团有限公司 | Process method for deep fixed-point feeding of blocking agent for high-permeability reservoir |
| CN115434659B (en) * | 2021-06-02 | 2024-03-01 | 中国石油天然气集团有限公司 | Technological method for deep fixed-point delivery of hypertonic reservoir plugging agent |
| CN113513298A (en) * | 2021-08-04 | 2021-10-19 | 广州海洋地质调查局 | Hot dry rock branch well same-well synchronous injection-production method and injection-production device |
| CN116218486A (en) * | 2021-12-03 | 2023-06-06 | 中国石油天然气集团有限公司 | Degradable sand carrying agent for drilling and completion fluid and preparation method thereof |
| CN116218486B (en) * | 2021-12-03 | 2024-05-31 | 中国石油天然气集团有限公司 | Degradable sand carrying agent for drilling and completion fluid and preparation method thereof |
| CN114458275A (en) * | 2021-12-30 | 2022-05-10 | 中国石油化工股份有限公司 | Multilayer small sand body comprehensive fracturing method for underwater diversion river sediment microphase |
| CN114458275B (en) * | 2021-12-30 | 2024-04-02 | 中国石油化工股份有限公司 | Comprehensive fracturing method for multilayer small sand bodies of sediment microphase of underwater diversion river |
| CN116498287A (en) * | 2023-06-29 | 2023-07-28 | 四川圣诺油气工程技术服务有限公司 | Height control method for sand fracturing artificial cracks |
| CN116498287B (en) * | 2023-06-29 | 2023-08-25 | 四川圣诺油气工程技术服务有限公司 | Height control method for sand fracturing artificial cracks |
Also Published As
| Publication number | Publication date |
|---|---|
| CN102925133B (en) | 2014-11-26 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN102925133B (en) | Fracturing fluid and fracturing method for controlling fracture extension height | |
| CN103013486B (en) | Fracturing fluid and fracturing method for improving laying efficiency of proppant in fractured fracture | |
| CN102022105B (en) | Large composite acid fracturing method of fracture cave type carbonate rock reservoir | |
| CN102952534B (en) | Low-damage fracturing fluid and fracturing method | |
| CA2923232C (en) | Method of optimizing conductivity in a hydraulic fracturing operation | |
| CN105089603B (en) | Reservoir transformation method for forming fracture network by temporary plugging and steering in fracture | |
| CN102913221B (en) | Volume transformation process of low permeability reservoir | |
| CN107387053A (en) | A kind of method that big passage major fracture cooperates with pressure break with complicated seam net | |
| AU2014405605B2 (en) | Enhancing complex fracture networks in subterranean formations | |
| CN108661617A (en) | A kind of fracturing process for increasing high-temperature stratum and manually stitching net complexity | |
| Lafollette | Key Considerations for Hydraulic Fracturing of Gas Shales | |
| US10899958B2 (en) | Liquid gas treatment fluids for use in subterranean formation operations | |
| US9752072B2 (en) | Propping compositions for enhancing fracture conductivity | |
| CN105317417B (en) | Fracturing method for medium-high-order coal bed gas reservoir | |
| Liao et al. | Lightweight proppants in unconventional oil and natural gas development: A review | |
| WO2015134022A1 (en) | Far-field diversion with pulsed proppant in subterranean fracturing operations | |
| CN112211608A (en) | Fracturing method for shale reservoir microfracture self-supporting | |
| CN104119853A (en) | A preparing method of a high-strength high-temperature-resistance air foam fracturing fluid | |
| DE112013007504T5 (en) | Fibers as drag reducing support fibers in low permeability subterranean applications | |
| US11391139B2 (en) | Staged propping of fracture networks | |
| RU2737455C1 (en) | Method of hydraulic fracturing of formation in conditions of high-dissected high-conductivity reservoir with low stress contrast of bridges | |
| US20180003021A1 (en) | Proppant suspension in shale fractures | |
| CN114622884B (en) | Full-support fracturing method and application of multi-scale cracks of oil and gas well | |
| Fenglan et al. | The applicable limits of the high strength gel system to the tight sandstone fractured reservoir in CO2 flooding | |
| US20230303911A1 (en) | Sand Consolidation Compositions And Methods Of Use |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| C14 | Grant of patent or utility model | ||
| GR01 | Patent grant |