CN115572587B - Acidic condition self-stabilization drilling fluid system - Google Patents

Acidic condition self-stabilization drilling fluid system Download PDF

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CN115572587B
CN115572587B CN202211235467.5A CN202211235467A CN115572587B CN 115572587 B CN115572587 B CN 115572587B CN 202211235467 A CN202211235467 A CN 202211235467A CN 115572587 B CN115572587 B CN 115572587B
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drilling fluid
sodium
acid
fluid system
water
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CN115572587A (en
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王志祥
韩庆
欧涛
张建东
许非
周小龙
尚杨
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Geological Team 403 Of Sichuan Geological And Mineral Exploration And Development Bureau
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    • 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
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/20—Natural organic compounds or derivatives thereof, e.g. polysaccharides or lignin derivatives
    • 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
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/20—Natural organic compounds or derivatives thereof, e.g. polysaccharides or lignin derivatives
    • C09K8/206—Derivatives of other natural products, e.g. cellulose, starch, sugars
    • 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
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/22—Synthetic organic compounds
    • C09K8/24—Polymers
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/141—Feedstock

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  • Chemical & Material Sciences (AREA)
  • Dispersion Chemistry (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Colloid Chemistry (AREA)

Abstract

The invention discloses a self-stabilizing drilling fluid system under an acidic condition, which comprises the following components: water, sodium-based rectorite, sulfonated lignite SMC and hydroxypropyl starch ether HPS; or water, sodium-based rectorite, sodium carboxymethyl cellulose Na-CMC and cationic polyacrylamide CPAM. The invention constructs a self-stabilizing drilling fluid system under an acidic condition through compounding optimization, and sodium-based rectorite, SMC, HPS, na-CMC and CPAM are respectively used as acid-invasion-resistant basic pulping materials, non-viscosity-increasing filtrate reducer, viscosity-increasing filtrate reducer and flocculant, and the raw materials are easy to obtain, and have small addition and low cost. The system can actively adapt to an acidic environment, has strong acid invasion resistance, and maintains stable performance indexes at pH=5. The invention provides a new technical scheme for the acidic stratum drilling fluid, facilitates the field application, management and performance maintenance of the drilling fluid, and has important practical significance for maintaining the stability of the well wall.

Description

Acidic condition self-stabilization drilling fluid system
Technical Field
The invention belongs to the technical field of geological core drilling, and particularly relates to an acidic condition self-stabilization drilling fluid system.
Background
Too high or too low a pH of the drilling fluid will adversely affect the performance of the drilling fluid and the stability of the borehole wall, and it is generally desirable to control the pH to a range of 8.5 to 10. The problems of easy bond breaking and failure of hydrolysis of the organic treating agent, promotion of hydration of clay minerals of sedimentary rock stratum, induced borehole wall instability and the like are caused by the too high pH value, and the too low pH value can cause a plurality of problems of obvious increase of water loss of drilling fluid, rapid change of viscosity, obvious reduction of colloid rate and the like. The drilling fluid encounters hydrogen sulfide, gypsum, humic acid and other factors, or the cations are increased to replace the adsorption in the clay through exchange adsorptionH of (2) + A rapid drop in pH will occur. The existing research is mainly focused on the aspects of influencing factors, influencing results, regulating methods and the like of the pH value reduction, the treatment method shows a passive defense idea, namely, buffer or pH regulating materials are continuously added into the drilling fluid, naOH is timely supplemented most widely, and the treatment method often increases the difficulty of on-site maintenance of the drilling fluid. The prior experience shows that the pH value can be quickly improved by supplementing NaOH into the drilling fluid, but the drilling fluid has the remarkable characteristics of easy rise and fall, and the performance index of the drilling fluid is obviously deteriorated. In addition, the mudstone can accelerate hydration under the action of NaOH, the stability of the well wall is poor, and the longer the drilled exposed hole Duan Yue is affected more obviously.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provide an acidic self-stabilizing drilling fluid system, which is not only convenient for on-site drilling fluid application, management and maintenance, but also can avoid side effects of greatly changing drilling fluid performance, weakening well wall stability and the like by adding NaOH, strong alkali weak acid salt and the like.
The aim of the invention is achieved by the following technical scheme: a self-stabilizing drilling fluid system under acidic conditions, the drilling fluid system being: water, sodium-based rectorite, sulfonated lignite SMC and hydroxypropyl starch ether HPS; or water, sodium-based rectorite, sodium carboxymethyl cellulose Na-CMC and cationic polyacrylamide CPAM.
Further, the mass percentage of the sodium-based rectorite is 2-5%.
Further, the sulfonated lignite SMC accounts for 1-3% of the total mass of the sulfonated lignite, and the hydroxypropyl starch ether HPS accounts for 0.2-0.4% of the total mass of the sulfonated lignite.
Further, the mass percentage of the sodium carboxymethyl cellulose Na-CMC is 0.1 to 0.3 percent, and the mass percentage of the cationic polyacrylamide CPAM is 0.01 to 0.03 percent.
Further, the acid condition self-stabilizing drilling fluid system is further a finely dispersed drilling fluid system: water +4% sodium-based rectorite +2% sulfonated lignite SMC +0.3% hydroxypropyl starch ether HPS.
Further, the acidic condition self-stabilizing drilling fluid system is further a non-dispersive drilling fluid system: water+3% sodium-based rectorite+0.2% sodium carboxymethyl cellulose Na-cmc+0.02% cationic polyacrylamide CPAM.
The invention has the following advantages: the invention constructs an acidic condition self-stabilization drilling fluid system through compound optimization, and changes a traditional mode of 'passive defense' with higher pH value maintained by adding NaOH, strong alkali weak acid salt and the like into a mode of 'active adaptation' with strong acid invasion resistance, not only can normally play a role under the higher pH value alkaline condition, but also can normally play a role under the lower pH value acidic condition, and the invention uses sodium-based rectorite, sulfonated lignite SMC, hydroxypropyl starch ether HPS, sodium carboxymethyl cellulose Na-CMC and cationic polyacrylamide CPAM as acid invasion resistant basic pulping materials, non-viscosity-increasing and fluid loss-reducing agents, viscosity-increasing and fluid loss-reducing agents and flocculating agents respectively. The drilling fluid system constructed can actively adapt to an acidic environment, has strong acid invasion resistance, and maintains stable performance indexes under the acidic condition of pH=5. The invention provides a new drilling fluid technical scheme for acidic stratum drilling, facilitates the field application, management and performance maintenance of the drilling fluid, and has important practical significance for maintaining the stability of the well wall.
Drawings
Fig. 1 is a diagram showing a change rule of the slurry gel rate of the basic pulping material.
FIG. 2 is a photograph of a 24h colloid of the acid/base addition of the base slurrying material slurry.
FIG. 3 is a photograph of a non-viscosified filtrate reducer slurry with acid for 24 hours.
FIG. 4 is a photograph of a viscosity enhancing fluid loss additive slurry with acid for 24 hours.
FIG. 5 is a photograph of flocculant slurry acid added for 24 hours.
FIG. 6 is a photograph showing a comparison of filtrate from a self-stabilizing drilling fluid system under acidic conditions before and after acid addition.
Detailed Description
The invention will be further described with reference to the accompanying drawings and examples, to which the scope of the invention is not limited: example 1: a dispersed drilling fluid system is as follows: water +4% sodium-based rectorite +2% sulfonated lignite SMC +0.3% hydroxypropyl starch ether HPS. Example 2: a dispersed drilling fluid system is as follows: water +2% sodium-based rectorite +1% sulfonated lignite SMC +0.2% hydroxypropyl starch ether HPS. Example 3: a dispersed drilling fluid system is as follows: water +5% sodium-based rectorite +3% sulfonated lignite SMC +0.4% hydroxypropyl starch ether HPS. Example 4: a non-dispersive drilling fluid system comprising: water+3% sodium-based rectorite+0.2% sodium carboxymethyl cellulose Na-cmc+0.02% cationic polyacrylamide CPAM.
Example 5: a non-dispersive drilling fluid system comprising: water +5% sodium-based rectorite +0.1% sodium carboxymethyl cellulose Na-CMC +0.03% cationic polyacrylamide CPAM.
Example 6: a non-dispersive drilling fluid system comprising: water+2% sodium-based rectorite+0.3% sodium carboxymethyl cellulose Na-cmc+0.01% cationic polyacrylamide CPAM.
The beneficial effects of the invention are illustrated by the following experiments:
1 laboratory apparatus and method
1.1 Experimental apparatus
The experimental facilities of making things ready: ZNN-D12S intelligent digital display twelve-speed rotary viscosimeter, SD6B medium pressure water loss meter, pH meter, EP-C extreme pressure lubrication meter, HS-17 magnetic stirrer, DQJ type low-speed powerful stirrer, su funnel viscosimeter and dropper.
Experiment reagent: hydrochloric acid with the mass fraction of 30%, naOH alkali solution with the mass fraction of 30%, bentonite A, bentonite B, sodium-based rectorite, sulfonated lignite SMC, potassium humate KHm, sulfonated phenolic resin SMP, sulfonated asphalt SAS, SM vegetable gum, welan gum, hydroxypropyl starch ether HPS, sodium carboxymethyl cellulose Na-CMC, xanthan gum, nonionic polyacrylamide PAM-3, anionic polyacrylamide PHP, cationic polyacrylamide DA-3 and cationic polyacrylamide CPAM.
1.2 Experimental methods
After the drilling fluid is prepared according to an experimental formula, the drilling fluid is kept stand for 24 hours to be fully hydrated. Under the condition of stirring, dilute hydrochloric acid is dripped into the drilling fluid by using a dropper to simulate acid invasion, and a pH meter is used for judging the change condition of the pH value of the drilling fluid in the dripping process. And when the pH value of the drilling fluid is 5, testing various performance indexes of the drilling fluid, and evaluating the acid invasion resistance of the drilling fluid.
2 acid intrusion resistant Material experiment
2.1 basic pulping Material
Selecting 110mL of bentonite A, bentonite B and sodium-based rectorite-based slurry with the addition amount of 4%, respectively dripping hydrochloric acid (or NaOH alkali solution) to a set pH value, pouring 100mL into a measuring cylinder, and observing the colloid ratio. The data of the serial numbers of relevant slurries, the drop adding amounts of hydrochloric acid and NaOH alkali solutions, the pH value and the like are shown in table 1, the change rule of the gel rate of the base slurry is shown in figure 1, and the photo of the acid/alkali adding 24h gel of the base slurry is shown in figure 2.
TABLE 1 pH change of drilling fluid base slurry after acid/base addition
Remarks: 50 drops of 2.559mL, with an average of about 0.0512 mL/drop
As can be seen from table 1, when the pH of the base slurry was made to be=5, the amount of hydrochloric acid required for sodium-based rectorite was significantly lower than that for the other two bentonites, indicating that the acid buffer capacity of sodium-based rectorite Dan Jiangye was significantly lower than that of bentonite. The reason is that rectorite is a 1:1 regular interlayer mineral composed of a mica-like layer and a montmorillonite-like layer, wherein the non-swelling mica-like layer is influenced by a non-hydrated cation interlayer to make the Cation Exchange Capacity (CEC) low, and the related data show that the CEC of rectorite is 36.04mmol/100g, and the CEC of bentonite based on sodium montmorillonite is 80-150 mmol/100g. Thus, sodium-based rectorite-based drilling fluids are more susceptible to being converted to pH levels comparable to the environment when subjected to acid attack.
The stability of the matrix colloid includes sedimentation stability and aggregation stability. As can be seen from fig. 1, at a base slurry ph=5, the gel ratios of bentonite a and bentonite B rapidly decreased within 12 hours, with 24 hours having gel ratios of 55% and 56%, respectively, and gradually stabilized around 50%. And the colloid rate of sodium-based rectories Dan Jiangye for 24 hours is 97%, and the later change is not great. After the bentonite slurry is immersed by acid, H + Generally by H 3 O + In the form of (a) to replace sodium ions (Na (H) 2 O)n] + (n=3.84), reduces the hydrated film thickness of montmorillonite while ionizing the aluminum hydroxyl groups in the aluminum oxy octahedron and using Al (OH) 2+ The colloid tends to show positive charges in form, zeta potential is reduced, electrostatic repulsive force is reduced, and the Brownian motion and the physical adsorption of polymolecular Van der Waals force are gradually obvious, so that water and soil separation is caused, bentonite colloid is coagulated and settled, and settlement stability is lost, so that colloid rate is obviously reduced. While sodium-based rectorite also contains a smectite-like layer, H is also present + However, the morphology of the colloidal dispersed phase particles is more special due to the mixed mica layer, and the flaky particles are easier to be connected in a mode of partial plane to end face, plane to partial plane and end to end face, so that the colloidal dispersed phase particles are more beneficial to forming a net structure relative to montmorillonite, and the sedimentation stability is maintained in a coarse dispersion state to a gel state.
When the pH of the base slurry was set to be 9, the difference in demand for NaOH aqueous alkali was not large. Na in general addition + The replacement colloid originally adsorbs H + The effect of the pH value of the slurry is not obvious, and the pH value of the slurry can be improved by a small amount of NaOH alkali solution. At the same time, under alkaline conditions OH - Can be adsorbed with the clay mineral lattice surface through hydrogen bonds to increase negative charge, thereby improving the hydration capability of the pulping material. Thus, bentonite and rectorite Dan Jiangye generally have better colloid ratios than neutral under alkaline conditions. From the rule of change of the basal pulp gel rate within 24-144 h, the sodium-based rectorite Dan Jiangye gel rate is higher than neutral in the meta-acid and meta-alkali environments, the time is prolonged, the advantages are gradually increased, and the gel rates under the acidic, neutral and alkaline environment conditions are 93%, 80% and 93% respectively at 144 h.
Thus, sodium-based rectorite is significantly better than bentonite as a base pulping material against acid attack.
2.2 viscosity-increasing and fluid loss additive
110mL of each of the SMC, KHm, SMP, SAS slurries with the addition amount of 2% are selected, hydrochloric acid is respectively added dropwise to a set pH value, and 100mL of each slurry is poured into a measuring cylinder for observation. The data of the drop amount of hydrochloric acid, the pH value, the 24-hour colloid ratio and the like are shown in Table 2, and the photo of the 24-hour colloid of the viscosity-increasing filtrate reducer slurry added with acid is shown in FIG. 3.
TABLE 2 pH and gel rate variation of non-viscosified fluid loss additive slurry after hydrochloric acid addition
As can be seen from FIG. 3, the SMC slurry was black, and there was no rapid precipitation after dropping hydrochloric acid, and the acid buffer capacity was more than that of the other 3 materials, and the gel rate at 24 hours was slightly lowered. SMC is prepared by utilizing the reaction of sodium humate and sodium hydroxymethylsulfonate, although humic acid is used as a high-molecular weak acid radical which is easy to agglomerate when meeting acid, sulfonate groups on molecules belong to strong acid groups with extremely strong water solubility, even under the acidic condition, the sodium humate can still keep better colloid ratio, and the light yellow clear liquid at the upper part still has a small amount of soluble matters. KHm the slurry is black, and the quick precipitation phenomenon is avoided after hydrochloric acid is added dropwise, but the colloid rate is obviously lower than that of SMC (surface Mount device) at 24 hours, and the supernatant is colorless and transparent. KHm is a complex mixture of high molecular hydroxycarboxylic acids, which is insoluble in fulvic acid, ulmic acid, and fulvic acid generated under acidic conditions, and is not easily kept colloidally stable. The SMP slurry is brownish red, and quickly turns to orange after hydrochloric acid is added dropwise, so that the chromaticity is obviously lightened, and no precipitation phenomenon exists. SMP is a water-soluble irregular linear polymer, which is susceptible to reactive degradation under acidic conditions, and has a substantial reduction in beneficial substances. SAS slurry is brownish black, precipitation phenomenon is obvious (2 mL precipitation), and chromaticity further becomes shallow after hydrochloric acid is added dropwise. SAS introduces sulfonic acid groups with extremely strong water solubility into polycyclic aromatic hydrocarbon compounds and heterocyclic compounds of asphalt, but may cause poorer solubility in water-based drilling fluids than other 3 types due to incomplete sulfonation.
Therefore, the sulfonated lignite SMC has better effect as an acid invasion resistant viscosity-increasing fluid loss additive.
2.3 viscosity increasing and fluid loss reducing agent
Selecting 110mL of SM vegetable gum, welan gum, HPS, na-CMC and xanthan gum slurry with the addition amount of 0.5%, respectively dripping hydrochloric acid to a set pH value, pouring 100mL into a measuring cylinder for observation. The data of the relevant hydrochloric acid dropping amount, pH value, funnel viscosity and the like are shown in Table 3, and the photo of the viscosity-increasing and fluid loss additive slurry added with acid for 24 hours is shown in FIG. 4.
TABLE 3 pH and funnel viscosity change of viscosity-enhancing fluid loss additives after hydrochloric acid addition
As can be seen from Table 3, the viscosity of the viscosity-increasing and fluid-reducing agent slurry was not significantly changed in the funnel before and after the acid addition. SM vegetable gum belongs to natural galactomannan, the acid buffer capacity of the slurry is obviously larger and is 2.8-4.7 times that of other several filtrate reducers, the color of the SM vegetable gum is slightly lightened after acid addition, part of natural fine particle vegetable scraps are easy to be precipitated by acid, and the precipitate is about 6mL. The welan gum belongs to microbial polysaccharide, and the slurry is colorless and transparent, but a large amount of transparent agglomerations appear when acid is added, so that the welan gum is not beneficial to on-site stirring. HPS is an anionic high molecular compound, the slurry is colorless and transparent, the change before and after acid addition is not obvious, and the mixture has a slight bubble phenomenon, but the viscosity is relatively low. Na-CMC is a carboxymethylated derivative of cellulose, the slurry is transparent and colorless, the change before and after acid addition is not obvious, and the viscosity is relatively higher. Xanthan gum is a microbial extracellular polysaccharide, and the slurry is colorless and transparent, and has insignificant change before and after adding acid, but relatively low viscosity.
Therefore, the hydroxypropyl starch ether HPS, sodium carboxymethyl cellulose Na-CMC and xanthan gum have better effects as acid invasion resistance, viscosity increasing and fluid loss additives.
2.4 flocculant
110mL of PAM-3, PHP, DA-3 and CPAM slurries with the addition amount of 0.3% are selected, hydrochloric acid is respectively dripped into the slurries to a set pH value, and 50mL of the slurries are poured into a measuring cylinder for observation. The data of the relevant hydrochloric acid dropping amount, pH value, funnel viscosity and the like are shown in Table 4, and the photo of the flocculant slurry added with acid for 24 hours is shown in FIG. 5.
TABLE 4 pH and funnel viscosity change of flocculant after hydrochloric acid addition
As is clear from Table 4, PHP slurry was excellent in adhesion, but white flocculent insoluble matter was remarkably produced after dropping hydrochloric acid, and was poor in acid intrusion resistance. The viscosity of PAM-3 and CPAM is reduced after acid addition, but the CPAM is relatively stable before and after acid addition, wherein CPAM slurry is easy to become turbid after being placed for a long time under a neutral condition, and the stability under an acidic condition is better. DA-3 is the biggest to other 3 materials dissolving degree of difficulty, and the easy transparent granule of form a large amount of beans shape when pulping stirring easily causes the jam in the pipeline when recycling, is inconvenient for on-the-spot use.
Therefore, the nonionic polyacrylamide PAM-3 and the cationic polyacrylamide CPAM have better effect as acid intrusion resistant flocculating agents.
3 acid invasion resistant drilling fluid formulation optimization
The optimized acid-invasion-resistant materials are compounded to prepare different types of acid-invasion-resistant drilling fluid systems, and various performances of the acid-invasion-resistant drilling fluid systems are tested, and experimental results are shown in Table 5.
Table 5 table for testing the performance of the drilling fluid
Formulas 1-4 are "finely divided drilling fluid systems". As shown in Table 5, the formulation 1 has better performance indexes, and the main performance indexes such as water loss, colloid ratio, funnel viscosity, dynamic-plastic ratio, lubricity and the like are more stable after acid addition, and the formulation is the simplest. Formulas 2, 3 and 4 are added with viscosity-increasing and fluid-reducing agents based on formula 1, so that the viscosity is increased properly and the water loss is further reduced, and the more complex stratum condition is dealt with. Wherein, HPS is added in the formula 2, no obvious agglomeration phenomenon is caused after acid is added, and the main index can be maintained well. Na-CMC is added in the formula 3, and the mixture has a slight agglomeration phenomenon after acid addition, but is easy to redisperse after stirring, and the main index of the mixture can be well maintained. The xanthan gum is added in the formula 4, obvious agglomeration phenomenon occurs after acid addition, stirring is not easy to disperse, the viscosity of a funnel is obviously increased, blockage is easily caused in a pipeline during recycling, and the field use is inconvenient. The stability observation is carried out on the compound drilling fluid stored for a long time (1 month), and the performance of the formula 2 is more stable. The comparison photographs of the filtrate before and after the acid addition of the self-stabilizing drilling fluid system under the acid condition of the formulas 1-4 are shown in fig. 6.
Formulations 5-6 are "undispersed drilling fluid systems". As shown in Table 5, the performance index of the catalyst is good, and the main index of the catalyst can be maintained well after acid addition. The preparation process finds that the performance of the formula 5 is greatly influenced by the addition sequence of materials, and the stability observation is carried out on the two formulas after long-term storage (1 month), so that the formula 6 is better. The filtrate is colorless transparent liquid before and after acid addition of the self-stabilizing drilling fluid system under the acidic condition of the formula 5-6, and the difference of the filtration loss is small.
Thus, formulation 2 was used as an "finely divided" drilling fluid system for acid intrusion and formulation 6 was used as an "undispersed" drilling fluid system for acid intrusion.
The foregoing is only a preferred embodiment of the present invention, but the scope of the present invention is not limited thereto, and any person skilled in the art who is skilled in the art to which the present invention pertains will appreciate that the technical scheme and the inventive concept according to the present invention are equally substituted or changed within the scope of the present invention.

Claims (6)

1. The acid condition self-stabilization drilling fluid system is characterized in that the drilling fluid system is: water, sodium-based rectorite, sulfonated lignite SMC and hydroxypropyl starch ether HPS; or water, sodium-based rectorite, sodium carboxymethyl cellulose Na-CMC and cationic polyacrylamide CPAM.
2. The acidic condition self-stabilizing drilling fluid system according to claim 1, wherein the sodium-based rectorite accounts for 2-5% by mass.
3. The acidic condition self-stabilization drilling fluid system according to claim 1 or 2, wherein the sulfonated lignite SMC is 1-3% by mass and the hydroxypropyl starch ether HPS is 0.2-0.4% by mass.
4. The acidic condition self-stabilization drilling fluid system according to claim 1 or 2, wherein the mass percentage of sodium carboxymethyl cellulose Na-CMC is 0.1-0.3%, and the mass percentage of cationic polyacrylamide CPAM is 0.01-0.03%.
5. The acid condition self-stabilizing drilling fluid system of claim 1, further comprising a finely divided drilling fluid system: water +4% sodium-based rectorite +2% sulfonated lignite SMC +0.3% hydroxypropyl starch ether HPS.
6. The acid condition self-stabilizing drilling fluid system of claim 1, further comprising a non-dispersive drilling fluid system: water+3% sodium-based rectorite+0.2% sodium carboxymethyl cellulose Na-cmc+0.02% cationic polyacrylamide CPAM.
CN202211235467.5A 2022-10-10 2022-10-10 Acidic condition self-stabilization drilling fluid system Active CN115572587B (en)

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Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN101942295A (en) * 2010-08-25 2011-01-12 中国地质大学（武汉） High temperature resisting rectorite water base drilling fluid for deep stratigraphical drilling

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JP7464047B2 (en) * 2019-04-24 2024-04-09 日産化学株式会社 Additive for well cement slurry and its manufacturing method, well cement slurry, and well cementing method

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Publication number Priority date Publication date Assignee Title
CN101942295A (en) * 2010-08-25 2011-01-12 中国地质大学（武汉） High temperature resisting rectorite water base drilling fluid for deep stratigraphical drilling

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累托石粘土的钠化与应用研究;陈济美;;资源环境与工程(01);第87-98+112+114页 *

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