CN106433581A - Clay-free high temperature resistance reservoir drilling fluid and preparation method thereof - Google Patents
Clay-free high temperature resistance reservoir drilling fluid and preparation method thereof Download PDFInfo
- Publication number
- CN106433581A CN106433581A CN201610842934.9A CN201610842934A CN106433581A CN 106433581 A CN106433581 A CN 106433581A CN 201610842934 A CN201610842934 A CN 201610842934A CN 106433581 A CN106433581 A CN 106433581A
- Authority
- CN
- China
- Prior art keywords
- high temperature
- temperature resistance
- drilling fluid
- reservoir drilling
- weight
- 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
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/06—Clay-free compositions
- C09K8/08—Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
Abstract
The invention relates to clay-free high temperature resistance reservoir drilling fluid and a preparation method of the fluid. The reservoir drilling fluid comprises 100 parts by weight of fresh water, 150-220 parts by weight of potassium formate, 0.2-0.25 parts by weight of pH (potential of hydrogen) regulator, 2-3 parts by weight of high temperature resistance fluid loss agent, 0.4-0.8 parts by weight of high temperature resistance shear strength improving agent, 5-8 parts by weight of calcium carbonate, and 0-200 parts by weight of manganese ore powder. The method comprises the steps of dissolving the parts by weight of potassium formate in the fresh water, and adding the parts by weight of pH regulator, high temperature resistance fluid loss agent, high temperature resistance shear strength improving agent, calcium carbonate and manganese ore powder for agitation. The reservoir drilling fluid can meet higher density requirements, has good stability, can keep stable when used at high temperature (such as 150-160 DEG C), has good reservoir protection performance, sedimentation stability and highly-deviated well cutting carrying capacity and can meet drilling requirements of a horizontal well.
Description
Technical field
The application relates to, but are not limited to a kind of reservoir drilling fluid and preparation method thereof, and in particular to but it is not limited to a kind of no soil
Phase and the reservoir drilling fluid of high temperature resistance and preparation method thereof.
Background technology
Reservoir drilling fluid is the working solution for using in Reservoir Section for taking into account drilling ＆ completion fluid function.Reservoir drilling fluid leads to
Often do not contain solid phase, sometimes can also add can acid-soluble solid phase adjusting density or pre- lost circulation prevention, but should be containing easily sealing
The bentonite of stifled reservoir or barite.At present, domestic proper no soil reservoir drilling fluid body mutually with no barite
System, density is typically all in 1.60g/cm3Within, and temperature resistance is general all within 120 DEG C.When in the face of higher density requirement
When, often also need to interpolation barite and increased.In addition, when bottom hole temperature (BHT) is relatively low, the performance of reservoir drilling fluid is by poly-
Compound can just be safeguarded, but under the hot conditionss more than 150 DEG C, conventional polymer can be degraded, and cause reservoir drilling fluid body
It is the deterioration of performance, so suitable for the difficult point that diplomatizes in the Solid Free reservoir drilling fluid under hot conditionss always industry.
Accordingly, it would be desirable to develop a kind of no soil phase with no barite and the high temperature resistance reservoir of higher density demand can be met
Drilling fluid.
Content of the invention
This application provides a kind of no native phase high temperature resistance reservoir drilling fluid.
The no native phase high temperature resistance reservoir drilling fluid that the application is provided, including each component of following weight portion：
In this application, term " fresh water " refers to water of the salinity below 5000.
In this application, manganese mineral powder not necessarily component, if add manganese mineral powder by reservoir drilling fluid in actual production
Density requirements determine.Potassium formate as prepare reservoir drilling fluid saline use when, it is recommended to use most high-density be less than
1.55g/cm3.In this application, the density of reservoir drilling fluid if desired is less than 1.55g/cm3, can be by adjusting formic acid
The addition of potassium is not required to add manganese mineral powder adjusting the density of reservoir drilling fluid；The density of reservoir drilling fluid if desired surpasses
1.55g/cm is crossed3, then need to add manganese mineral powder.
In presently filed embodiment, the pH adjusting agent can be sodium hydroxide and/or potassium hydroxide etc..
In presently filed embodiment, the heat resisting fluid loss reducing agent can be Rhizoma Solani tuber osi crosslinked starch.
Alternatively, the Rhizoma Solani tuber osi crosslinked starch can be Rhizoma Solani tuber osi crosslinked starch commonly used in the art, such as BeiJing ZhongKe's day
Rise Science and Technology Ltd. or open the Rhizoma Solani tuber osi crosslinked starch of lateral skill Chemical Co., Ltd. production.
In presently filed embodiment, the Rhizoma Solani tuber osi crosslinked starch being capable of at least 140 DEG C of temperature resistance.
In presently filed embodiment, the high temperature resistance extracting and cutting agent can be xanthan gum.
Alternatively, the xanthan gum is the xanthan gum of pavilion biochemistry limited company production in Ordos City.
In presently filed embodiment, the Calcium Carbonate can be the different calcium carbonate powder of particle diameter.The particle diameter is not
The particle diameter of size grading, i.e. calcium carbonate powder of same calcium carbonate powder and the proportioning of the calcium carbonate powder of different-grain diameter are permissible
Selected by method commonly used in the art, for example, according to physical property (such as porosity, the permeability of different reservoirs
Deng), using ideal packing theory by this area specialty software for calculation (such as COSL
The software OPTIBRIDGE of Ideal Particle Expert, MI SWACO) calculate acquisition.
In presently filed embodiment, the relative density of the manganese mineral powder can be 4.7g/cm3, mean diameter is permissible
About 0.5 μm.Alternatively, the manganese mineral powder is manganese mineral powder micromax of Ai Ken company of Norway production.
Present invention also provides a kind of method for preparing no native phase high temperature resistance reservoir drilling fluid as above.
The method of the preparation that the application is provided no native phase high temperature resistance reservoir drilling fluid, including：
The potassium formate of the weight portion is dissolved in fresh water；
PH adjusting agent, heat resisting fluid loss reducing agent, high temperature resistance extracting and cutting agent, Calcium Carbonate and the manganese mineral powder of the weight portion is added,
Stirring.
In the application, the effect of each component is as follows：
(1) potassium formate
Improve collaboration inhibition, temperature resistance ability and the density of reservoir drilling fluid.
(2) pH adjusting agent
The pH value of regulation system.
(3) heat resisting fluid loss reducing agent
With preferable heat-resisting property, for the rheological characteristic of reservoir drilling fluid is adjusted, carry with high temperature resistance in this application and cutting
Agent is used together can play a part of Synergistic to the regulation of rheological characteristic.
(4) high temperature resistance extracting and cutting agent
Viscosity, yield value and the shear force of system can be improved when used in fresh water, salt-water mud, add little amount
Make system that higher viscosity is produced, and have filtrate reducing effect concurrently.Its another distinguishing feature be with excellent shear thinning behavior
Can, the thixotropy of drilling fluid can be effectively improved, improves flow pattern.
(5) Calcium Carbonate
For reservoir is blocked, reduce the infringement of solid phase and liquid phase to reservoir, control the filtration property of drilling fluid.
(6) manganese mineral powder
Main component is Mn3O4, belong to acid-soluble drilling fluid heavy weight additive, with excellent suspending power in drilling fluid.
Compared with prior art, the Advantageous Effects obtained by the application are as follows：
1st, the density of the reservoir drilling fluid of the application can be adjusted interior in a big way, and need not add swelling or
Or barite just disclosure satisfy that higher density requirement, most high-density can reach 2.2g/cm3.
2nd, the reservoir drilling fluid of the application has good stability, when using under high temperature (for example, 150-160 DEG C)
Remain to keep stable performance.
3rd, the reservoir drilling fluid of the application has good reservoir protection performance, and permeability resume figure is higher than 90%.
4th, the reservoir drilling fluid of the application has stronger gel strength, and structure no longer persistently strengthens after quickly being formed, tool
There are good sedimentation stability and high angle hole that the carrying capacity of rock is taken, disclosure satisfy that horizontal well drilling needs.
Description of the drawings
Fig. 1 is the gel strength trendgram over time of the reservoir drilling fluid of the embodiment of the present application 1.
Specific embodiment
Below by embodiment, presently filed embodiment is described, it will be appreciated by the person skilled in the art that these
Specific embodiment only indicates that to the enforcement technical scheme for reaching the purpose of the application and selecting, be not to technical scheme
Limit.According to teachings of the present application, it is obvious in conjunction with prior art to the improvement of technical scheme, belongs to the application
The scope of protection.
Raw material and reagent used in following examples, if no special instructions, is conventional commercially available prod.
Embodiment 1
660g potassium formate is substantially dissolved in 300mL fresh water, then in the condition of the high-speed stirred of 11000 turns/min
Under, it is slowly added to 0.66g sodium hydroxide, 6.0g Rhizoma Solani tuber osi crosslinked starch (Beijing Zhongke Risheng Technology Co., Ltd.), 1.6g xanthan
Glue (in Ordos City pavilion biochemistry limited company), Calcium Carbonate of the 24.0g through grain composition (including particle diameter be 1200 mesh,
800 mesh and the calcium carbonate powder of 400 mesh, and the weight ratio of three is 1:1:1) and 184g manganese mineral powder (Ai Ken company of Norway,
Micromax), high-speed stirred 20min.
Embodiment 2
660g potassium formate is substantially dissolved in 300mL fresh water, then in the condition of the high-speed stirred of 11000 turns/min
Under, it is slowly added to 0.66g sodium hydroxide, 6.0g Rhizoma Solani tuber osi crosslinked starch (Beijing Zhongke Risheng Technology Co., Ltd.), 1.6g xanthan
Glue (in Ordos City pavilion biochemistry limited company), Calcium Carbonate of the 24.0g through grain composition (including particle diameter be 1200 mesh,
800 mesh and the calcium carbonate powder of 400 mesh, and the weight ratio of three is 1:1:1) and 435g manganese mineral powder (Ai Ken company of Norway,
Micromax), high-speed stirred 20min.
Comparative example 1
Under conditions of the high-speed stirred of 11000 turns/min, slowly by 0.88g sodium hydroxide, 8.0g Rhizoma Solani tuber osi crosslinked starch
(Beijing Zhongke Risheng Technology Co., Ltd.), 2.0g xanthan gum (biochemistry limited company in pavilion in Ordos City), 24.0g warp
The Calcium Carbonate of grain composition is added in 400mL fresh water, high-speed stirred 20min.
Reservoir drilling fluid performance evaluation
1st, traditional performance evaluation
By the reservoir drilling fluid of example 1-2 and comparative example 1, at 160 DEG C, heat is rolled 16 hours, is then determined under its room temperature
HTHP filter loss under rheological characteristic, API filtration and 150 DEG C, 3.5MPa, the results are shown in Table 1.
The traditional performance evaluating data of the no native phase high temperature resistance reservoir drilling fluid system of table 1
As it can be seen from table 1 compounding potassium formate and manganese mineral powder cause the reservoir drilling fluid of embodiment 1-2 with higher
Density, and the reservoir drilling fluid of embodiment 1-2 has preferable heat-resisting property and relatively low filter loss.
2nd, sedimentation stability evaluation
Three parts of identical reservoir drilling fluids are prepared according to embodiment 1, ageing can is respectively put into, is then vertically put into baking
In case, maintain oven temperature to be 160 DEG C, take out after placing 3 days, 5 days and 7 days in baking oven respectively, measure each ageing can
The density of top and the reservoir drilling fluid of bottom, and according to (formula 1) the calculated settlement factor, the results are shown in Table 2.
In formula：
SF settles the factor, dimensionless；
ρtopSample upper layer density, unit is gram (g/cm per cubic centimeter3)；
ρbottomSample bottom density, unit is gram (g/cm per cubic centimeter3).
2 sedimentation stability test data of table
It has been generally acknowledged that SF just there's almost no the danger of sedimentation within 0.52 in industry, from table 2 it can be seen that the application
All not there is the danger for settling in the reservoir drilling fluid of embodiment 1 in 7 days, explanation has good stability.
3rd, gel strength evaluation
The gel strength of primary evaluation sample and the relatedness of time, that is, reservoir drilling fluid can shape in a short period of time
Become Weak Gels structure, and the characteristic for no longer increasing over time after reaching some strength.Embodiment 1 after will be aging
Reservoir drilling fluid be put in rotating cylinder viscometer, respectively 10s, 30s, 1min, 2min, 5min, 10min, 20min, 30min,
60min and 120min measure its gel strength.The results are shown in Table 3 and Fig. 1.
3 gel strength of table changes over experiments experiment data
According to industrial practice, more than 10Pa, gel strength represents that gel strength is stronger.This Shen be can be seen that from table 3 and Fig. 1
Please the reservoir drilling fluid of embodiment 1 there is stronger gel strength, structure no longer persistently strengthens after quickly being formed, and illustrates which has
Good sedimentation stability and high angle hole take the carrying capacity of rock, disclosure satisfy that horizontal well drilling needs.
4th, reservoir protection performance is evaluated
With reference to China National Petroleum industry standard SY/T6540-2002《Damage of drilling fluid and completion fluid oil reservoir Lab-evaluation
Method》, reservoir protection performance evaluation is carried out to the reservoir drilling fluid of embodiment 1.Key step is as follows：
1. rock core prepares, and determines master data, dries evacuation and uses normal saline solution saturation 16h.
2. using rock core Flow Meter at 160 DEG C kerosene permeability Ko；
3. at 160 DEG C, 200-s/minLower reversely dynamic pollution 120min；
4. kerosene permeability K after determining pollution using rock core Flow Meter at 160 DEG Cos, and combine (formula 2) calculating infiltration
Rate recovery value Ro, result of the test is as shown in table 4.
Ro=Kos/Ko× 100% (formula 2)
In formula：
RoPermeability resume figure, unit is %.
KoKerosene permeability before rock core pollution, unit is mD；
KosKerosene permeability after rock core pollution, unit is mD.
4 rock core master data of table
5 rock core displacement test result of table
The permeability resume figure of reservoir drilling fluid of the embodiment of the present application 1 be can be seen that from table 4-5 all more than 90%,
Show that system has good reservoir protection effect.
The reservoir drilling fluid of the embodiment of the present application 2 is evaluated using method same as described above, is obtained in that and reality
Apply the similar performance parameter of the reservoir drilling fluid of example 1.
The preferred embodiment for being only the application, not makes any formal and substantial restriction to the application.
Those skilled in the art, in the range of without departing from technical scheme, when using disclosed above technology contents
And a little change, modification and the equivalent variations for developing that makes are the Equivalent embodiments of the application；Meanwhile, all according to the application
The change of substantial technological any equivalent variations that above example is made, modification with develop etc. all in the application by right
In the range of requirement is defined.
Claims (8)
1. a kind of no native phase high temperature resistance reservoir drilling fluid, the reservoir drilling fluid includes each component of following weight portion：
2. no native phase high temperature resistance reservoir drilling fluid according to claim 1, wherein, the pH adjusting agent be
And/or potassium hydroxide.
3. no native phase high temperature resistance reservoir drilling fluid according to claim 1, wherein, the heat resisting fluid loss reducing agent be
Crosslinked starch.
4. no native phase high temperature resistance reservoir drilling fluid according to claim 3, wherein, the Rhizoma Solani tuber osi crosslinked starch being capable of temperature resistance
At least 140 DEG C.
5. no native phase high temperature resistance reservoir drilling fluid according to claim 1, wherein, the high temperature resistance extracting and cutting agent be
Glue.
6. no native phase high temperature resistance reservoir drilling fluid according to claim 1, wherein, the Calcium Carbonate is the different carbon of particle diameter
Sour calcium powder, the size grading of the calcium carbonate powder be according to the physical property of different reservoirs using ideal packing theory come
Select.
7. no native phase high temperature resistance reservoir drilling fluid according to claim 1, wherein, the relative density of the manganese mineral powder is
4.7g/cm3, mean diameter be 0.5 μm.
8. a kind of method of the no native phase high temperature resistance reservoir drilling fluid for preparing according to any one of claim 1-7, including：
The potassium formate of the weight portion is dissolved in fresh water；
PH adjusting agent, heat resisting fluid loss reducing agent, high temperature resistance extracting and cutting agent, Calcium Carbonate and the manganese mineral powder of the weight portion is added, stirring.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610842934.9A CN106433581B (en) | 2016-09-22 | 2016-09-22 | It is a kind of without soil reservoir drilling fluid mutually resistant to high temperatures and preparation method thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610842934.9A CN106433581B (en) | 2016-09-22 | 2016-09-22 | It is a kind of without soil reservoir drilling fluid mutually resistant to high temperatures and preparation method thereof |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN106433581A true CN106433581A (en) | 2017-02-22 |
| CN106433581B CN106433581B (en) | 2019-04-26 |
Family
ID=58167010
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610842934.9A Active CN106433581B (en) | 2016-09-22 | 2016-09-22 | It is a kind of without soil reservoir drilling fluid mutually resistant to high temperatures and preparation method thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN106433581B (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110079283A (en) * | 2018-01-26 | 2019-08-02 | 中石化石油工程技术服务有限公司 | A method of improving Environment-protecting Drilling Fluids inorganic agent temperature resistance |
| CN110105927A (en) * | 2019-06-11 | 2019-08-09 | 中国石油化工股份有限公司 | Low solid phase formates drilling and completing fluids resistant to high temperatures and preparation method thereof |
Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101255333A (en) * | 2008-04-21 | 2008-09-03 | 北京中科日升科技有限公司 | Anti-temperature starch composition for drilling liquid and preparation method thereof |
| CN101948678A (en) * | 2010-06-29 | 2011-01-19 | 西南石油大学 | Nontoxic potassium formate polyalcohol drilling fluid |
| CN102127402A (en) * | 2010-12-15 | 2011-07-20 | 中国海洋石油总公司 | High-temperature-resistant clay-phase-free hypotonic reservoir stratum drilling fluid |
| CN102504771A (en) * | 2011-10-13 | 2012-06-20 | 中国海洋石油总公司 | Water-based drilling fluid system for deepwater operation and preparation method thereof |
| CN103045190A (en) * | 2012-12-11 | 2013-04-17 | 中国石油集团川庆钻探工程有限公司 | Soluble weighting salt low-damage drilling fluid and preparation method thereof |
| CN103275680A (en) * | 2013-05-22 | 2013-09-04 | 克拉玛依市金鑫科技有限公司 | No-clay low-solid phase horizontal well section drilling fluid and preparation method thereof |
| CN104558217A (en) * | 2014-12-30 | 2015-04-29 | 北京中科日升科技有限公司 | Cross-linked starch for drilling fluid and preparation method thereof |
| CN105295865A (en) * | 2015-09-15 | 2016-02-03 | 西南石油大学 | Soilless potassium formate water-based drilling fluid for drilling shale |
-
2016
- 2016-09-22 CN CN201610842934.9A patent/CN106433581B/en active Active
Patent Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101255333A (en) * | 2008-04-21 | 2008-09-03 | 北京中科日升科技有限公司 | Anti-temperature starch composition for drilling liquid and preparation method thereof |
| CN101948678A (en) * | 2010-06-29 | 2011-01-19 | 西南石油大学 | Nontoxic potassium formate polyalcohol drilling fluid |
| CN102127402A (en) * | 2010-12-15 | 2011-07-20 | 中国海洋石油总公司 | High-temperature-resistant clay-phase-free hypotonic reservoir stratum drilling fluid |
| CN102504771A (en) * | 2011-10-13 | 2012-06-20 | 中国海洋石油总公司 | Water-based drilling fluid system for deepwater operation and preparation method thereof |
| CN103045190A (en) * | 2012-12-11 | 2013-04-17 | 中国石油集团川庆钻探工程有限公司 | Soluble weighting salt low-damage drilling fluid and preparation method thereof |
| CN103275680A (en) * | 2013-05-22 | 2013-09-04 | 克拉玛依市金鑫科技有限公司 | No-clay low-solid phase horizontal well section drilling fluid and preparation method thereof |
| CN104558217A (en) * | 2014-12-30 | 2015-04-29 | 北京中科日升科技有限公司 | Cross-linked starch for drilling fluid and preparation method thereof |
| CN105295865A (en) * | 2015-09-15 | 2016-02-03 | 西南石油大学 | Soilless potassium formate water-based drilling fluid for drilling shale |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110079283A (en) * | 2018-01-26 | 2019-08-02 | 中石化石油工程技术服务有限公司 | A method of improving Environment-protecting Drilling Fluids inorganic agent temperature resistance |
| CN110105927A (en) * | 2019-06-11 | 2019-08-09 | 中国石油化工股份有限公司 | Low solid phase formates drilling and completing fluids resistant to high temperatures and preparation method thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| CN106433581B (en) | 2019-04-26 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN101851491B (en) | Method for preparing fluid loss additive for drilling fluid | |
| CN104650823B (en) | Height ooze extra-high ooze reservoir protective material composition and drilling fluid and application thereof | |
| US20200283673A1 (en) | Thermosensitive Self-plugging Bentonite and Preparation Method Thereof and Water-based Drilling Fluid | |
| CN104927805A (en) | High-density water-based drilling fluid applicable to continental deposit sensitive shale formation | |
| US11542425B1 (en) | Leak-proof lost-circulation control water-based drilling fluid composition and preparation method and use thereof | |
| CN103396771A (en) | Degradable drilling fluid based on nano material | |
| CN109233762A (en) | A kind of drilling fluid, preparation method and application | |
| CN104212418B (en) | High density well control fluids | |
| CN106433581A (en) | Clay-free high temperature resistance reservoir drilling fluid and preparation method thereof | |
| CN108949127A (en) | Low solid phase superhigh temperature water base drilling fluid and preparation method thereof | |
| CN108690599B (en) | Erosion acidizing fluid for clay minerals and preparation method thereof | |
| CN114716984A (en) | Cementing and plugging type wall fixing agent for water-based drilling fluid and preparation method and application thereof | |
| Gang et al. | A green shale inhibitor developed from lignin sulfonate and the mechanism study | |
| CN111876138B (en) | Carbon-based tackifier and preparation method and application thereof | |
| CN101948679B (en) | A kind of Intelligent reservoir drilling completion fluid system and preparation method thereof | |
| CN105176506B (en) | Density workover fluid and its preparation method in a kind of acid salt Solid Free | |
| CN105018053A (en) | Recyclable micro-foam drilling fluid and preparation method therefor | |
| CN115466603B (en) | 240 ℃ resistant and salt resistant plugging type water-based drilling fluid, and preparation method and application thereof | |
| CN104312563A (en) | Cationic surfactant for micro-foam drilling fluid and preparation method thereof | |
| CN103450861A (en) | Protection drilling fluid for low-pressure reservoir | |
| CN113444505B (en) | Self-adaptive plugging isolation liquid system and preparation method thereof | |
| CN107325229A (en) | A kind of preparation method of the organic fluid loss additive of heat and salinity tolerance | |
| CN113956854B (en) | Viscosity reducer, drilling fluid and preparation method and application of viscosity reducer and drilling fluid | |
| CN106520083A (en) | Moderate-and-high-temperature oil well cement fluid loss additive and preparation method thereof | |
| CN106010483A (en) | Water-based drilling fluid system and preparation method and application thereof |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| CB02 | Change of applicant information |
Address after: 100010 Chaoyangmen North Street, Dongcheng District, Dongcheng District, Beijing Applicant after: China Offshore Oil Group Co., Ltd. Applicant after: China Oilfield Services Limited Address before: 100010 Chaoyangmen North Street, Dongcheng District, Dongcheng District, Beijing Applicant before: China National Offshore Oil Corporation Applicant before: China Oilfield Services Limited |
|
| GR01 | Patent grant | ||
| GR01 | Patent grant |