CN107288575A - A kind of well intensifying method - Google Patents
A kind of well intensifying method Download PDFInfo
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- CN107288575A CN107288575A CN201710559046.0A CN201710559046A CN107288575A CN 107288575 A CN107288575 A CN 107288575A CN 201710559046 A CN201710559046 A CN 201710559046A CN 107288575 A CN107288575 A CN 107288575A
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- 238000000034 method Methods 0.000 title claims abstract description 31
- 238000005553 drilling Methods 0.000 claims abstract description 36
- 239000012530 fluid Substances 0.000 claims abstract description 29
- 239000007788 liquid Substances 0.000 claims abstract description 19
- CDBYLPFSWZWCQE-UHFFFAOYSA-L sodium carbonate Substances [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims abstract description 13
- 229920006318 anionic polymer Polymers 0.000 claims abstract description 12
- 229910000029 sodium carbonate Inorganic materials 0.000 claims abstract description 11
- 229920006317 cationic polymer Polymers 0.000 claims abstract description 9
- 230000008569 process Effects 0.000 claims abstract description 9
- 239000001110 calcium chloride Substances 0.000 claims abstract description 8
- 229910001628 calcium chloride Inorganic materials 0.000 claims abstract description 8
- 230000003014 reinforcing effect Effects 0.000 claims abstract description 8
- 229920000642 polymer Polymers 0.000 claims abstract description 5
- 239000000835 fiber Substances 0.000 claims description 7
- 229920003043 Cellulose fiber Polymers 0.000 claims description 5
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 claims description 5
- 229920002401 polyacrylamide Polymers 0.000 claims description 5
- GFLJTEHFZZNCTR-UHFFFAOYSA-N 3-prop-2-enoyloxypropyl prop-2-enoate Chemical compound C=CC(=O)OCCCOC(=O)C=C GFLJTEHFZZNCTR-UHFFFAOYSA-N 0.000 claims description 4
- VVJKKWFAADXIJK-UHFFFAOYSA-N Allylamine Chemical compound NCC=C VVJKKWFAADXIJK-UHFFFAOYSA-N 0.000 claims description 4
- 229920000371 poly(diallyldimethylammonium chloride) polymer Polymers 0.000 claims description 4
- 229920000728 polyester Polymers 0.000 claims description 3
- 229920002134 Carboxymethyl cellulose Polymers 0.000 claims description 2
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 2
- 229920003171 Poly (ethylene oxide) Polymers 0.000 claims description 2
- 239000002253 acid Substances 0.000 claims description 2
- 239000001768 carboxy methyl cellulose Substances 0.000 claims description 2
- 235000010948 carboxy methyl cellulose Nutrition 0.000 claims description 2
- 239000008112 carboxymethyl-cellulose Substances 0.000 claims description 2
- 238000005660 chlorination reaction Methods 0.000 claims description 2
- DLNKOYKMWOXYQA-UHFFFAOYSA-N dl-pseudophenylpropanolamine Natural products CC(N)C(O)C1=CC=CC=C1 DLNKOYKMWOXYQA-UHFFFAOYSA-N 0.000 claims description 2
- DLNKOYKMWOXYQA-APPZFPTMSA-N phenylpropanolamine Chemical compound C[C@@H](N)[C@H](O)C1=CC=CC=C1 DLNKOYKMWOXYQA-APPZFPTMSA-N 0.000 claims description 2
- 229960000395 phenylpropanolamine Drugs 0.000 claims description 2
- -1 polyoxyethylene Polymers 0.000 claims description 2
- 239000002994 raw material Substances 0.000 claims 3
- 150000001768 cations Chemical class 0.000 claims 1
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 abstract description 8
- 229910000019 calcium carbonate Inorganic materials 0.000 abstract description 4
- 239000007787 solid Substances 0.000 abstract description 2
- 239000003795 chemical substances by application Substances 0.000 description 17
- 238000007789 sealing Methods 0.000 description 11
- 239000002002 slurry Substances 0.000 description 7
- 239000000463 material Substances 0.000 description 5
- 101100288310 Arabidopsis thaliana KTI2 gene Proteins 0.000 description 4
- 230000008901 benefit Effects 0.000 description 4
- 239000002245 particle Substances 0.000 description 4
- 230000005764 inhibitory process Effects 0.000 description 3
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- 229920002845 Poly(methacrylic acid) Polymers 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 229910002804 graphite Inorganic materials 0.000 description 2
- 239000010439 graphite Substances 0.000 description 2
- 230000002209 hydrophobic effect Effects 0.000 description 2
- 239000007908 nanoemulsion Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 238000005728 strengthening Methods 0.000 description 2
- 241000258971 Brachiopoda Species 0.000 description 1
- 241000336847 Luda Species 0.000 description 1
- 241000276489 Merlangius merlangus Species 0.000 description 1
- 241000237852 Mollusca Species 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000003044 adaptive effect Effects 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 230000000996 additive effect Effects 0.000 description 1
- 230000003592 biomimetic effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 239000001913 cellulose Substances 0.000 description 1
- 229920002678 cellulose Polymers 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000013329 compounding Methods 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- FLKPEMZONWLCSK-UHFFFAOYSA-N diethyl phthalate Chemical group CCOC(=O)C1=CC=CC=C1C(=O)OCC FLKPEMZONWLCSK-UHFFFAOYSA-N 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000008014 freezing Effects 0.000 description 1
- 238000007710 freezing Methods 0.000 description 1
- 239000008187 granular material Substances 0.000 description 1
- 238000000227 grinding Methods 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 238000003475 lamination Methods 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000010534 mechanism of action Effects 0.000 description 1
- 239000012528 membrane Substances 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 238000003786 synthesis reaction Methods 0.000 description 1
- 229920001169 thermoplastic Polymers 0.000 description 1
- 239000004416 thermosoftening plastic Substances 0.000 description 1
- 230000010148 water-pollination Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Compositions Of Macromolecular Compounds (AREA)
Abstract
The present invention provides a kind of method strengthened for well, including first with slush pump toward being pumped into 1 ~ 3m in well3Liquid is spaced, then according to cationic polymer solution, Na2CO3Solution, CaCl2Solution, the order of anionic polymer solution are pumped into aforesaid liquid in well, and the volume that is pumped into of every kind of liquid is 1 ~ 3m3, then pause 5 minutes, this is a circulation；After 5 ~ 10 circulate, then it is pumped into interval 1 ~ 3m of liquid3, it is to complete borehole wall reinforcing process that above-mentioned solution finally is replaced out into well using drilling fluid.Using calcium carbonate and the self-assembling technique of polymer in this method, fine and close, firm skin covering of the surface is formed on drilling shaft lining, for being reinforced to the borehole wall, the ' Safe Density Windows of drilling fluid is widened, ensures drilling safety.This method is the field conduct technique formed on the basis of bionical solid wall is theoretical.
Description
Technical field
The present invention relates to field of oil drilling, more particularly to a kind of well intensifying method.
Background technology
During oil gas drilling, wellbore stability is the problem of being widely present.Borehole well instability easily causes hole collapse, contracting
The down hole problems such as footpath, leakage, bit freezing and reservoir pollution and accident, can not only delay drilling period, increase drilling cost,
Follow-up oil producing operation can be influenceed.It is also possible to scrap part well or even scrap whole well when serious.Cause borehole well instability
Factor sum up and can be divided into three major types, including the factor such as geology, drilling fluid physics and chemistry, drillng operation.Change drilling well
The characteristic of liquid is one of main means of current wellbore stability, and forms fine and close and tough and tensile mud cake is then to ensure wellbore stability
Key factor.
At present, it is many to be solved using sealing agent is added in drilling fluid for Wellbore Stability.Should in research and scene
In, there are many sealing agents and drilling fluid system.Such as, nanoemulsions and film-forming inhibitor SD-805 are added to black by Chen Erding
In color MMH drilling fluid, film forming high inhibition nanometer closure drilling fluid is developed（Film forming high inhibition nanometer blocks grinding for drilling fluid
Study carefully Drilling and completion fluids, 2011）.The huge specific surface area of the non-ionic nanoemulsions of hydrophobic type increases the profit of drilling fluid
Slip and anti-collapse property.Make its shut-off capacity, absorption because nonionic surface active agent SD-805 can form surface chemistry potential difference
It is very capable.The synergy of multiple material causes the drilling fluid has in terms of wellbore stability, reduction reservoir damage very big
Advantage.
Ultra-low invasion fluid technology is combined by Liu Baosheng with broad spectrum type temporary plugging technique, develops a kind of new film forming envelope
Blocking drilling fluid (CBF), its main component is film forming agent, diverting agent and ultra-low penetration agent.Its mechanism of action is：This drilling fluid runs into
During pore constriction, several sealing agent interactions form one layer of plugging film at leakage, prevent the intrusion of solid phase and liquid phase.With it
His additive for drilling fluid compounding use, caving-preventing ability is more preferably.Field application explanation in Luda 10-1 oil fields：The envelope of the drill-in fluid
Stifled property, inhibition, lubricity, anti-collapse property, oil layer protection performance can meet field requirement.
It is adaptive that Lv Kaihe is developed by main component of shielding diverting agent ZPJ, changeability particle and filling strengthening agent
Temporary plugging drilling fluid, the great advantage of the sealing agent can be carried out closure, Ying Ping without pore-size distribution is had any actual knowledge of
Temporary blocking drilling fluid is covered, the great advantage of the sealing agent can be carried out closure without pore-size distribution is had any actual knowledge of, because this
Sealing agent is substantially amphiphilic polymers, hydrophobic inner layer and hydrophily outer layer row into close membrane there is two-dimentional unlimitedness and one
Dimension finiteness can block a wide range of aperture.In addition, the addition of strengthening agent reduces the permeability of film.Test result indicates that：Should
Drilling fluid sealing ratiod nearly 100%, plugging strength reaches 9MPa.
BP exploration companies develop a kind of multifunctional drilling fluid with stress shielding theory for theoretical foundation.The closure of hyposmosis
Agent is formed at crack can realize the plugged zone of pressure packing, and fill the grain that principle determines sealing agent particle according to preferable
Footpath.BP exploration company field tests show：This drilling fluid has good plugging effect to the minute crack on shale, sandstone.
A kind of thermoplastic poly esters sealing agent FDJ-EF suitable for water-base drilling fluid is developed to law of an imperial court.In certain temperature
In the range of degree, FDJ-EF particles can be deformed, and pressure difference can be squeezed into crack, and the closure of hyposmosis is formed in crack
Layer.Beyond softening temperature, particle does not deform therefore does not possess shut-off capacity.FDL-EF sealing agents can to nearly borehole wall microcrack
To play significant plugging action, it can effectively solve the problems, such as to avoid brittle property mud shale borehole well instability.
The Rebound of Karen Phillips company develops a kind of elastic graphite sealing agent.Elastic graphite chemical stability is high, and
And with gel the same elasticity and morphotropism, can first shrink expand afterwards under stress, can be according to hole, the size in crack
Adaptively blocked with shape.
These researchs play important impetus to the bio-mimetic syntheses of biomineralization material, but still failing to grow into has
The bionical material of natural whiting structure (the calcium carbonate shell of the height rule in such as mollusk, half nacre of brachiopod)
Material, or method and material property need further raising.Meanwhile, the film prepared using self-assembling technique is not applied to also
, there be very big expand space in petroleum works field in this regard.
The content of the invention
The purpose of the present invention is that there is provided a kind of method strengthened for well, the party the problem of presence for prior art
Using calcium carbonate and the self-assembling technique of polymer in method, fine and close, firm skin covering of the surface is formed on drilling shaft lining, for well
Wall is reinforced, and widens the ' Safe Density Windows of drilling fluid, ensures drilling safety.
This method is the field conduct method formed on the basis of bionical solid wall is theoretical.Its inventive technique scheme is so
Realize：
Prepare interval liquid respectively in five drilling fluid slurry tanks（0.1% ~ 0.8%, wt%）, cationic polymer solution（0.1%
~ 0.8%, wt%）、Na2CO3Solution（1% ~ 3%, wt%）、CaCl2Solution（1% ~ 3%, wt%）, anionic polymer solution（0.1%~
0.8%, wt%）.
First, using slush pump toward being pumped into 1 ~ 3m in well3Liquid is spaced, then according to cationic polymer solution, Na2CO3
Solution, CaCl2Solution, the order of anionic polymer solution be pumped into aforesaid liquid in well, and every kind of liquid is pumped into body
Product is 1 ~ 3m3, then pause 3-10 minutes, this was a circulation.After 5 ~ 10 circulate, then it is pumped into interval 1 ~ 3m of liquid3, so
It is to complete borehole wall reinforcing process that above-mentioned solution is replaced out into well using drilling fluid afterwards.
In such scheme, cationic polymer solution PH scopes are 4.0 ± 0.5；Anionic polymer solution PH scopes are
8.0±0.5。
In such scheme, interval liquid is superbhort fiber cellulose fiber, polyester superbhort fiber, polyacrylamide phenol, high viscous carboxylic first
The solution of one or more of formulated in combination in base cellulose.
In such scheme, the cationic polymer for preparing cationic polymer solution is PDDA（Phthalic acid diethyl
Omega-diol diacrylate）、PAH（Poly- allylamine hydrochlorid）、WSCP（Polyoxyethylene chlorination diformazan imonium）In it is one or more of
Combination.
In such scheme, the anionic polymer for preparing anionic polymer solution is PAA（Phenylpropanolamine HC1）、
PMAA（Polymethylacrylic acid）、APAM（Hydrolyzed polyacrylamide）In one or more of combinations.
The present invention has the advantage that compared with prior art：
The principle that the borehole wall is reinforced in the present invention is that the deposition layer by layer of calcium carbonate granule is realized using self-assembling technique, forms heavy with this
Lamination Reinforcing Shaft.The sedimentary of the method production has extraordinary adhesion property, compactness and toughness, well reinforcing effect
Preferably.
Embodiment
Embodiment 1：
Prepare the PDDA solution that mass percent is 0.1% respectively in different slurry tanks（pH=3.5）, mass percent 1%
Na2CO3Solution, the CaCl of mass percent 1%2The PAA solution of solution, mass percent 0.1%（pH=7.5）Anionic polymer
Solution.Then it is 0.1% superbhort fiber cellulose fiber solution mass percent to be prepared in slurry tank, and is stirred.First, it is sharp
With slush pump toward being pumped into 1 m in well3Superbhort fiber cellulose fiber solution, then it is pumped into 1 m respectively in order3 PDDA solution, 1 m3
Na2CO3Solution, 1 m3 CaCl2Solution, 1 m is pumped into again3PAA solution, pauses 5 minutes, this is pumped into process as one after being pumped into
Circulation.After 8 circulate, then it is pumped into 1 m3Superbhort fiber cellulose fiber solution, then recycles drilling fluid by above-mentioned solution top
It is to complete borehole wall reinforcing process to replace out well.
Embodiment 2：
Prepare the WSCP solution that mass percent is 0.2% respectively in different slurry tanks（pH=4）, mass percent 2%
Na2CO3Solution, the CaCl of mass percent 2%2The PMAA solution of solution, mass percent 0.2%（pH=8）Anionic polymer is molten
Liquid.Then it is 0.2% polyacrylamide phenol solution mass percent to be prepared in slurry tank, and is stirred.First, mud is utilized
Stock pump is toward being pumped into 1 m in well3Polyacrylamide phenol solution, then it is pumped into 1 m respectively in order3 WSCP solution, 1 m3 Na2CO3
Solution, 1 m3 CaCl2Solution, 1 m is pumped into again3PMAA solution, pauses 5 minutes, this is pumped into process and followed as one after being pumped into
Ring.After 5 circulate, then it is pumped into 1 m3Polyacrylamide phenol solution, then recycles drilling fluid to replace out above-mentioned solution
Well is to complete borehole wall reinforcing process.
Embodiment 3：
Prepare the PAH solution that mass percent is 0.8% respectively in different slurry tanks（pH=4）, mass percent 3%
Na2CO3Solution, the CaCl of mass percent 3%2The APAM solution of solution, mass percent 0.8%（pH=8）Anionic polymer is molten
Liquid.Then it is 0.2% high viscous cmc soln that mass percent is prepared in slurry tank, and is stirred.First, it is sharp
With slush pump toward being pumped into 1 m in well3The viscous cmc soln of height, then it is pumped into 1 m respectively in order3 WSCP solution, 1
m3 Na2CO3Solution, 1 m3 CaCl2Solution, 1 m is pumped into again3PMAA solution, after being pumped into pause 5 minutes, this be pumped into process as
One circulation.After 10 circulate, then it is pumped into 1 m3The viscous carboxymethyl cellulose of height, then recycles drilling fluid by above-mentioned solution
It is to complete borehole wall reinforcing process to replace out well.
Claims (3)
1. a kind of well intensifying method, it is characterised in that：
It is configured to respectively0.1%~0.8%wt%Interval liquid,0.1%~0.8%wt%Cationic polymer solution,1%~3%wt%'s
Na2CO3Solution,1%~3%wt%CaCl2Solution and0.1%~0.8%w%tAnionic polymer solution；
First with slush pump toward being pumped into 1 ~ 3m in well3Liquid is spaced, then according to cationic polymer solution, Na2CO3Solution,
CaCl2Solution, the order of anionic polymer solution are pumped into aforesaid liquid in well, every kind of liquid be pumped into volume for 1 ~
3m3, then pause 3-8 minutes, this was a circulation；
After 5 ~ 10 circulate, then it is pumped into interval 1 ~ 3m of liquid3, above-mentioned solution finally is replaced out into well using drilling fluid has been
Into borehole wall reinforcing process.
2. a kind of well intensifying method according to claim 1, it is characterised in that：The cationic polymer solution pH models
Enclose for 4.0 ± 0.5；Anionic polymer solution pH scopes are 8.0 ± 0.5.
3. a kind of well intensifying method according to claim 1, it is characterised in that：The raw material for preparing interval liquid is ultrashort fibre
One or more in cellulose fiber, polyester superbhort fiber, polyacrylamide phenol, high viscous carboxymethyl cellulose；Prepare cation
The raw material of polymer solution is PDDA, poly- allylamine hydrochlorid, polyoxyethylene chlorination two
One or more in first imonium；Prepare anionic polymer solution raw material be phenylpropanolamine HC1, polymethylacrylic acid,
One or more in hydrolyzed polyacrylamide.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710559046.0A CN107288575A (en) | 2017-07-11 | 2017-07-11 | A kind of well intensifying method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710559046.0A CN107288575A (en) | 2017-07-11 | 2017-07-11 | A kind of well intensifying method |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN107288575A true CN107288575A (en) | 2017-10-24 |
Family
ID=60100516
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710559046.0A Pending CN107288575A (en) | 2017-07-11 | 2017-07-11 | A kind of well intensifying method |
Country Status (1)
| Country | Link |
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| CN (1) | CN107288575A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107461171A (en) * | 2017-07-11 | 2017-12-12 | 中石化石油工程技术服务有限公司 | A kind of method for preventing that well from collapsing |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0587071A1 (en) * | 1992-09-08 | 1994-03-16 | Gkss-Forschungszentrum Geesthacht Gmbh | Polyelectrolyte composite membrane |
| CN102553461A (en) * | 2012-03-20 | 2012-07-11 | 北京工业大学 | Inorganic/organic composite nanofiltration membrane and preparation method thereof |
| CN103897674A (en) * | 2012-12-28 | 2014-07-02 | 中国石油化工股份有限公司 | Borehole cleaning liquid and preparation method thereof |
| CN104405371A (en) * | 2014-09-26 | 2015-03-11 | 中国石油大学(华东) | Method for increasing borehole wall stability and reducing filtration |
| CN105479876A (en) * | 2014-09-27 | 2016-04-13 | 中国石油化工集团公司 | Nano-bionic laminar film and preparation method therefor |
| CN105731817A (en) * | 2014-12-12 | 2016-07-06 | 中石化胜利石油工程有限公司钻井工艺研究院 | A method of assembling montmorillonite layer by layer on a solid surface |
| US9431487B2 (en) * | 2013-01-11 | 2016-08-30 | International Business Machines Corporation | Graphene layer transfer |
-
2017
- 2017-07-11 CN CN201710559046.0A patent/CN107288575A/en active Pending
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0587071A1 (en) * | 1992-09-08 | 1994-03-16 | Gkss-Forschungszentrum Geesthacht Gmbh | Polyelectrolyte composite membrane |
| CN102553461A (en) * | 2012-03-20 | 2012-07-11 | 北京工业大学 | Inorganic/organic composite nanofiltration membrane and preparation method thereof |
| CN103897674A (en) * | 2012-12-28 | 2014-07-02 | 中国石油化工股份有限公司 | Borehole cleaning liquid and preparation method thereof |
| US9431487B2 (en) * | 2013-01-11 | 2016-08-30 | International Business Machines Corporation | Graphene layer transfer |
| CN104405371A (en) * | 2014-09-26 | 2015-03-11 | 中国石油大学(华东) | Method for increasing borehole wall stability and reducing filtration |
| CN105479876A (en) * | 2014-09-27 | 2016-04-13 | 中国石油化工集团公司 | Nano-bionic laminar film and preparation method therefor |
| CN105731817A (en) * | 2014-12-12 | 2016-07-06 | 中石化胜利石油工程有限公司钻井工艺研究院 | A method of assembling montmorillonite layer by layer on a solid surface |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107461171A (en) * | 2017-07-11 | 2017-12-12 | 中石化石油工程技术服务有限公司 | A kind of method for preventing that well from collapsing |
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Application publication date: 20171024 |
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