CN115160997A - Plugging material, plugging drilling fluid, preparation method of plugging drilling fluid and plugging method - Google Patents
Plugging material, plugging drilling fluid, preparation method of plugging drilling fluid and plugging method Download PDFInfo
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- CN115160997A CN115160997A CN202210945424.XA CN202210945424A CN115160997A CN 115160997 A CN115160997 A CN 115160997A CN 202210945424 A CN202210945424 A CN 202210945424A CN 115160997 A CN115160997 A CN 115160997A
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- plugging
- drilling fluid
- polysulfonate
- curing
- smtz
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- 238000005553 drilling Methods 0.000 title claims abstract description 217
- 239000012530 fluid Substances 0.000 title claims abstract description 185
- 239000000463 material Substances 0.000 title claims abstract description 116
- 238000000034 method Methods 0.000 title claims abstract description 28
- 238000002360 preparation method Methods 0.000 title claims abstract description 18
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 52
- 239000007788 liquid Substances 0.000 claims abstract description 12
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 claims abstract description 3
- 239000002002 slurry Substances 0.000 claims description 73
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 42
- 239000002245 particle Substances 0.000 claims description 32
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 claims description 30
- 239000000843 powder Substances 0.000 claims description 21
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 19
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 18
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- BSVBQGMMJUBVOD-UHFFFAOYSA-N trisodium borate Chemical compound [Na+].[Na+].[Na+].[O-]B([O-])[O-] BSVBQGMMJUBVOD-UHFFFAOYSA-N 0.000 claims description 6
- RYFMWSXOAZQYPI-UHFFFAOYSA-K trisodium phosphate Chemical compound [Na+].[Na+].[Na+].[O-]P([O-])([O-])=O RYFMWSXOAZQYPI-UHFFFAOYSA-K 0.000 claims description 6
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- VTHJTEIRLNZDEV-UHFFFAOYSA-L magnesium dihydroxide Chemical compound [OH-].[OH-].[Mg+2] VTHJTEIRLNZDEV-UHFFFAOYSA-L 0.000 claims description 3
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- TWNQGVIAIRXVLR-UHFFFAOYSA-N oxo(oxoalumanyloxy)alumane Chemical compound O=[Al]O[Al]=O TWNQGVIAIRXVLR-UHFFFAOYSA-N 0.000 description 11
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- 229910000278 bentonite Inorganic materials 0.000 description 6
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- 229910018626 Al(OH) Inorganic materials 0.000 description 1
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Images
Classifications
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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
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/426—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells for plugging
-
- 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
- C09K8/03—Specific additives for general use in well-drilling compositions
-
- 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
- C09K8/03—Specific additives for general use in well-drilling compositions
- C09K8/032—Inorganic additives
-
- 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
- C09K8/03—Specific additives for general use in well-drilling compositions
- C09K8/035—Organic additives
-
- 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
-
- 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
-
- 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
- Y02W—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO WASTEWATER TREATMENT OR WASTE MANAGEMENT
- Y02W30/00—Technologies for solid waste management
- Y02W30/50—Reuse, recycling or recovery technologies
- Y02W30/91—Use of waste materials as fillers for mortars or concrete
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Inorganic Chemistry (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Dispersion Chemistry (AREA)
- Geochemistry & Mineralogy (AREA)
- Curing Cements, Concrete, And Artificial Stone (AREA)
Abstract
The invention discloses a plugging material, a plugging drilling fluid, a preparation method of the plugging drilling fluid and a plugging method. The plugging material comprises the following components in percentage by mass: 52 to 64 percent of curing main agent, 20 to 30 percent of structural assistant and 14 to 18 percent of excitant. The liquid phase part of the polysulfonate drilling fluid provides a necessary water environment for dissolving the exciting agent. After the plugging material is doped, the excitant is firstly dissolved in the polysulfonate drilling fluid, and the alkalinity of a polysulfonate drilling fluid system is enhanced, so that the pH value of the polysulfonate drilling fluid system is increased to more than 12 from the initial pH value of 8-9, and a necessary alkaline environment is provided for the solidification of the plugging material. When the alkalinity of the drilling fluid is enhanced, the active oxide component in the curing main agent can generate corrosion reaction in a strong alkaline environment, so that the active elements in the curing main agent are dissolved out to generate the silica-alumina gel, and the polysulfonate drilling fluid is gradually converted from a liquid state to a solid state. The structural assistant does not participate in the reaction, and mainly plays a role in filling aggregate and enhancing the strength of a solidified body.
Description
Technical Field
The invention relates to the technical field of drilling and completion engineering in oil and gas exploration and development operation, in particular to a plugging material, a plugging drilling fluid, a preparation method of the plugging drilling fluid and a plugging method.
Background
The cured material is a commonly used plugging material based on drilling. Conventional cured materials require separate slurry preparation in advance and pumping into the leaking layer in the form of a slug, and curing and plugging are realized in the stratum. However, the material has the problems of dilution and pollution, incapability of protecting a reservoir, high construction risk and the like, so that the application of the material in leakage control is greatly limited.
Leakage control is usually realized by technologies such as plugging with plugging materials, underbalanced drilling, pressure-controlled drilling and the like, wherein plugging with the plugging materials is the most widely applied technology in the field, and mainly comprises a bridging technology (plugging is realized by bridging particle plugging materials in cracks), a gel plugging technology and a conventional cement slurry plugging technology. In addition, for the leakage control of the reservoir interval, not only efficient plugging during the well drilling and completion process but also effective removal (i.e. meeting the reservoir protection requirement) after well drilling and completion are required so as to restore the seepage capability of the fracture channel at a later stage. The bridging technology can be applied to reservoirs and non-reservoirs, and the reservoir section application can adopt acid-soluble plugging materials, such as calcium carbonate particles. The key to the successful application of the technology is to realize the matching of the size distribution of the bridging material and the width of the leakage crack, otherwise, the condition of 'door sealing' or blocking failure is easily caused. However, there still exist many difficulties for downhole fracture width identification, such as complex natural fracture system, new fractures generated during drilling, inaccurate positioning of lost positions, etc., which results in the failure to obtain accurate and reliable fracture width values. The difficulties greatly limit the successful application of the bridge plugging technology, the site can achieve the expected purpose only by depending on the experience of engineers or adopting multiple times of plugging tests, and the plugging efficiency and the success rate are low. The gel plugging technology is realized by pumping liquid gel material into a leakage layer and realizing cross-linking to form high-viscosity gel material underground to plug a leakage channel. The cement slurry is injected into the leaking layer by adopting the conventional cement slurry for plugging, and is solidified in the leaking layer so as to realize the purpose of plugging. The cement stone formed after the cement is solidified can effectively strengthen the shaft and greatly improve the bearing capacity. The gel plugging technology and the cement slurry plugging technology can realize plugging without depending on underground crack width identification, but because the plugging zones formed by gel materials and set cement cannot be removed in acid dissolution, self-degradation and other modes, the two technologies cannot be applied to a reservoir section.
Chinese patent No. CN202011275486.1 discloses a plugging material for solving the above problems, which is prepared by mixing powder of plugging material, polymer liquid and pure water, and during construction, solidified plugging slurry needs to be pumped to a leaking layer in the form of a slug, and a spacer fluid needs to be arranged before and after the slug. If other liquids such as drilling and completion fluid and formation fluid are mixed in the solidified plugging slurry, the components of the plugging slurry are changed, which can cause the change of the curing reaction environment and influence the curing process of the plugging slurry; in addition, the concentration of the plugging slurry is reduced due to the mixing of other liquid. This results in a substantial reduction in the pressure-bearing capacity of the consolidated body and the inability to form an effective sealing band. The lost circulation material also cannot be used with any drilling fluids currently available.
Disclosure of Invention
Aiming at the defects in the prior art, the invention provides the plugging material, the plugging drilling fluid, the preparation method of the plugging drilling fluid and the plugging method, which solve the problem that the existing plugging material cannot be used together with the polysulfonate drilling fluid.
In order to achieve the purpose of the invention, the invention adopts the technical scheme that:
the leak-stopping material comprises the following components in percentage by mass: 52 to 64 percent of curing main agent, 20 to 30 percent of structural assistant and 14 to 18 percent of excitant.
Further, the mass ratio of the curing main agent to the structural auxiliary agent to the exciting agent is 7:3:2.
further, the curing main agent comprises at least one of aluminum oxide, fly ash and silicon dioxide.
Further, the activator comprises at least one of sodium hydroxide, potassium hydroxide, sodium carbonate and lime powder.
Further, the structural auxiliary agent comprises at least one of calcium carbonate powder, quartz powder, magnesium hydroxide and inert bridging materials.
Providing a leaking stoppage drilling fluid which comprises a leaking stoppage material and a polysulfonate drilling fluid; wherein the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.3-0.5: 1.
further, the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.4:1.
further, a retarder is also included; wherein the mass ratio of the retarder to the plugging material is 0.1-0.4: 1.
further, the retarder comprises at least one of sodium borate, sodium gluconate and sodium phosphate, and the mass ratio of the retarder to the plugging material is 0.3:1.
the preparation method of the leaking stoppage drilling fluid comprises the following steps of:
a1, determining the dosage of the curing leaking stoppage slurry required to be prepared according to a leaking stoppage scheme;
a2, calculating the dosage of the plugging material and the retarder required to be doped according to the dosage of the solidified plugging slurry;
a3, adding an exciting agent into the polysulfonate drilling fluid, fully stirring for at least 30min, and standing until the exciting agent is completely dissolved;
a4, adding a retarder, and fully stirring for at least 10min;
and A5, adding the curing main agent and the structural auxiliary agent, and stirring until the curing main agent and the structural auxiliary agent are uniformly mixed with the polysulfonate drilling fluid to finish the preparation of the plugging drilling fluid.
Further, the step A5 is followed by the step of:
and A6, adding calcium carbonate particles, and stirring for at least 10min.
The leakage stoppage method comprises the following steps of:
b1, plugging preparation: the drilling tool for plugging the drill pipe is pulled out, the drilling tool is lowered to 50m above a leaking layer, and the leakage speed is measured in a circulating mode to obtain the actual condition of the well leakage;
b2, field slurry preparation: determining the quantity of the required solidified plugging slurry according to the actual conditions of the lost circulation and preparing the plugging drilling fluid;
b3, replacing plugging slurry by injection: calculating the amount of displacement mud, and tripping the drill to be above a safe liquid level according to the height of the liquid level of the leaking stoppage drilling fluid after the leaking stoppage drilling fluid is displaced until the displacement is completed;
b4, tripping waiting for plugging: the well is pulled out to a safe well section or a casing pipe, and the well is static for 8 to 12 hours;
b5, drilling, plugging and checking: removing the drill, replacing the drilling tool, drilling down to detect the plug, circulating in sections during the drilling down, determining the plug surface when meeting the plug, and drilling the plug;
and B6, when the normal discharge circulation is not leaked after the drilling and plugging, the drilling is resumed to finish the plugging.
The invention has the beneficial effects that:
the plugging material and the retarder are mixed into the polysulfonate drilling fluid system according to the required preparation proportion, are uniformly stirred and are pumped into the stratum. The activator belongs to an alkaline substance which is easy to dissolve in water, and the liquid phase part of the polysulfonate drilling fluid provides a necessary water environment for dissolving the activator. After the plugging material is doped, the excitant is firstly dissolved in the polysulfonate drilling fluid, and the alkalinity of a polysulfonate drilling fluid system is enhanced, so that the pH value of the polysulfonate drilling fluid system is increased to more than 12 from the initial pH value of 8-9, and a necessary alkaline environment is provided for the solidification of the plugging material. After the alkalinity of the drilling fluid is enhanced, active oxide components in the curing main agent can generate corrosion reaction under a strong alkaline environment, so that active elements (Si, al, mg and the like) in the drilling fluid are dissolved out to generate silicon-aluminum gel, and the polysulfonate drilling fluid is gradually converted from a liquid state to a solid state. The structural assistant does not participate in the reaction, and mainly plays a role in filling aggregate and enhancing the strength of a solidified body.
The plugging zone formed by the plugging material/the plugging drilling fluid can be removed by acid dissolution. The incompletely reacted metal oxide in the curing main agent, the acid-soluble component in the structural assistant, the residual activator and the like are substances which are easy to react with the acid liquor. The acid liquor contacts with the solidified body, the acid liquor reacts with the acid-soluble part in the solidified body, the structure of the solidified body collapses in the reaction process, the plugging zone is removed, and a small amount of residual solid phase can be carried to the shaft through the backflow action of formation fluid, so that the aim of removing the acid-soluble part is finally achieved.
Drawings
FIG. 1 is a graph showing the curing effect of the activator in example 1 using sodium hydroxide;
FIG. 2 is a graph showing the curing effect of the activator in example 1 using potassium hydroxide;
FIG. 3 is a graph showing the curing effect of the activator in example 1 when sodium carbonate or lime powder is used;
FIG. 4 is a graph showing the results of the experiment in example 1;
FIG. 5 is a SEM photograph and a corresponding energy spectrum of example 1;
FIG. 6 is a schematic diagram of the hydration reaction process in example 1;
FIG. 7 is a scanning electron micrograph of the sample after being maintained at constant temperature of 120 ℃ for 24 hours;
FIG. 8 is a scanning electron micrograph of the sample after being cured at a constant temperature of 90 ℃ for 48 hours;
FIG. 9 shows a consolidated body after static curing of different amounts of plugging material (SMTZ-A) incorporated; wherein the amount incorporated in FIG. 9 (a) is 10%, the amount incorporated in FIG. 9 (b) is 20%, the amount incorporated in FIG. 9 (c) is 30%, the amount incorporated in FIG. 9 (d) is 40%, and the amount incorporated in FIG. 9 (e) is 50%;
FIG. 10 is a graph showing the effect of SMTZ-A incorporation on solidification shrinkage;
FIG. 11 shows that the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.3-0.5: 1 hour curing time diagram;
fig. 12 shows that the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.3:1, effect of retarder on curing time;
fig. 13 shows that the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.4:1, effect of retarder on curing time;
fig. 14 shows that the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.5:1, a graph of the effect of retarder on curing time;
FIG. 15 is a graph of the relationship between the dynamic setting time of the lost circulation drilling fluid and the retarder loading;
FIG. 16 is a graph of the effect of SMTZ-A incorporation on polysulfonate drilling fluid rheology;
FIG. 17 is a graph of the effect of SMTZ-A incorporation on polysulfonate drilling fluid fluidity index and consistency factor;
FIG. 18 is a graph of the effect of SMTZ-A incorporation on thixotropy of polysulfonic drilling fluids;
FIG. 19 is a graph showing the results of the immersion acid dissolution test; wherein FIG. 19 (a) is the result of soaking for 5s, FIG. 19 (b) is the result of soaking for 10min, and FIG. 19 (c) is the result of soaking for 33 min;
FIG. 20 is a schematic diagram showing the results of a contact acid dissolution experiment;
FIG. 21 is a graph of the effect of SMTZ-A incorporation on polysulfonate drilling fluid density.
Fig. 22 shows the incorporation mass ratio of 0.3:1, the particle size distribution diagram of the SMTZ-a polysulfonate drilling fluid;
fig. 23 shows the incorporation mass ratio of 0.5:1, the particle size distribution diagram of the SMTZ-a polysulfonate drilling fluid;
FIG. 24 is a graph of the relationship between the solidified polysulfonate drilling fluid and the amount of lost circulation material incorporated.
Detailed Description
The following description of the embodiments of the present invention is provided to facilitate the understanding of the present invention by those skilled in the art, but it should be understood that the present invention is not limited to the scope of the embodiments, and it will be apparent to those skilled in the art that various changes may be made without departing from the spirit and scope of the invention as defined and defined in the appended claims, and all matters produced by the invention using the inventive concept are protected.
Example 1:
the plugging material comprises the following components in percentage by mass: 52 to 64 percent of curing main agent, 20 to 30 percent of structural assistant and 14 to 18 percent of excitant. The main function of the curing main agent is to perform a curing reaction to form a solidified body. The main function of the structural auxiliary agent is to improve the strength of the consolidation body. The main function of the activator is to promote the curing reaction.
During the use process, the curing main agent is hydrolyzed and hydrated by the mineral substances and water on the surface of the particles, and the generated hydrated product is mainly mixed gel substances. Part of the dispersed gel substances can fix free water as crystal water, and the crystal compound is finally formed along with the full progress of hydration reaction; the other part can react with soil particles with certain activity physically or chemically to form a cluster particle structure.
The exciting agent adopts an alkaline substance which is easy to dissolve in water, and the liquid phase part of the polysulfonate drilling fluid provides a necessary water environment for dissolving the exciting agent. After the plugging material is doped, the excitant is firstly dissolved in the polysulfonate drilling fluid, and the alkalinity of a polysulfonate drilling fluid system is enhanced, so that the pH value of the polysulfonate drilling fluid system is increased to more than 12 from the initial pH value of 8-9, and a necessary alkaline environment is provided for the solidification of the plugging material. When the alkalinity of the polysulfonate drilling fluid is enhanced, active oxide components in the curing main agent can generate corrosion reaction in a strong alkaline environment, so that active elements (Si, al, mg and the like) in the curing main agent are dissolved out to generate silica-alumina gel, and the polysulfonate drilling fluid is gradually converted from a liquid state to a solid state.
All the structural assistants are insoluble in water and can be ground into fine powder. Can be cemented by the hydrated intermediate product and provides certain structural strength and toughness for the final consolidated body. The structural assistant does not participate in the reaction, and mainly plays a role in filling aggregate and enhancing the strength of a solidified body.
Preferably, the mass ratio of the curing main agent to the structural assistant to the activator is 7:3:2. the main solidifying agent comprises at least one of aluminum oxide, fly ash and silicon dioxide, wherein the fly ash contains a large amount of silicon dioxide (SiO) 2 ) (amorphous and crystalline), aluminum oxide (Al) 2 O 3 ). The activator comprises at least one of sodium hydroxide, potassium hydroxide, sodium carbonate and lime powder. The structural auxiliary agent comprises at least one of calcium carbonate powder, quartz powder, magnesium hydroxide and inert bridging materials, and the inert bridging materials can be walnut shells, fibers and the like.
Taking the reaction of the curing base and the activator (base) as an example:
the reaction equation of the aluminum oxide and the sodium hydroxide in the aqueous solution is as follows: al (aluminum) 2 O 3 +2NaOH+3H 2 O＝2Na[Al(OH) 4 ]。
Chemical equation for silica reaction with caustic soda: siO 2 2 +2NaOH＝Na 2 SiO 3 +H 2 O。
Therefore, the aluminum oxide, the fly ash and the silicon dioxide all meet the relevant requirements of the curing main agent in the scheme.
In this embodiment, based on the curing main agent being aluminum oxide and the structural auxiliary agent being calcium carbonate powder, when the activator is sodium hydroxide, the curing is continued for 24 hours at an experimental temperature of 90 ℃, as shown in fig. 1, so that the best curing effect can be obtained. When the excitant adopts potassium hydroxide, the curing is continuously carried out for 24 hours at the experimental temperature of 90 ℃, as shown in figure 2, although the periphery of the solidified body is locally cracked, the obtained solidified body still has enough strength, and the curing effect of the solidified body meets the plugging requirement. When the excitant adopts sodium carbonate or lime powder, as shown in figure 3, the consolidation effect of the consolidation body is slightly lower than that of the consolidation body adopting potassium hydroxide, mainly only local consolidation occurs, but the strength and compactness of the local consolidation still meet the plugging index, and when the size of the crack is smaller than the size of the local consolidation, the sodium carbonate or the lime powder is adopted as the excitant and still can meet the plugging requirement.
Therefore, the performance of the plugging material of aluminum oxide, calcium carbonate powder and sodium hydroxide is the best, but the plugging material adopting other curing main agents, structural auxiliary agents and exciting agents has the same reaction principle with the best plugging material, so that tests on other aspects are only carried out on the plugging material with the best performance (aluminum oxide, calcium carbonate powder and sodium hydroxide), and the following test conclusion can be analogized to the plugging material with other formulas.
Due to the influence of the formation temperature, when the plugging material is used alone, the curing time window is narrow, so that the drilling fluid doped with the plugging material is solidified in a shaft, and drilling accidents occur. Therefore, according to actual requirements, a proper retarding mode may be selected to prolong the curing time, so that the plugging material can smoothly enter the leaking layer with the target depth. The commonly used retardation modes mainly comprise a direct addition retarder, a coating method, a non-aqueous liquid carrying method and the like, the feasibility, the operability and the cost are comprehensively considered, the retarder is directly added for carrying out the delayed plugging slurry solidification experiment, the retarder with the best delayed solidification effect is screened out through the retarder optimization experiment, the solidification main agent of the plugging material adopts aluminum oxide, the structural auxiliary agent adopts calcium carbonate powder, the exciting agent adopts sodium hydroxide, and the retarder for carrying out the experiment comprises sodium borate, sodium gluconate and sodium phosphate.
After each group of samples start to react, whether the samples reach the initial setting state is respectively tested at three time points of 60min, 90min and 100min, if the samples approach the initial setting state, the samples are tested once every 5min, and if the samples do not reach the initial setting state, the samples are tested once every 10-20 min. In order to clearly compare the retarding effects of different retarders, solidification time is taken to draw a solidification time cylinder, and the experimental result is shown in fig. 4, wherein ZB-1 represents a leaking stoppage material without adding a retarder, ZB-5 represents a leaking stoppage material with adding sodium borate, ZB-6 represents a leaking stoppage material with adding sodium gluconate, and ZB-7 represents a leaking stoppage material with adding sodium phosphate. As can be seen from fig. 4, all 3 retarders can prolong the curing time of the plugging material, wherein the prolonging time is sodium borate at most, and the prolonging time is 55% longer than that of the plugging material without the retarder. Compared with the retardation time without the retarder, the retardation time of the sodium gluconate and the sodium phosphate is respectively prolonged by 15 percent and 5 percent.
In this embodiment, a hydration reaction mechanism experiment is performed on the plugging material, table 1 shows a hydration reaction mechanism experimental design, SMTZ-a in table 1 indicates a plugging material (i.e., a solid material and a solidified material) containing aluminum oxide, calcium carbonate powder and sodium hydroxide, S1 indicates a solidified main agent, J1 indicates a structural assistant, and HN1 indicates a retarder. The reaction temperature is 90 ℃, the reaction time is 24h, and the experiment JL-2 added with distilled water and complete SMTZ-A is used as a control group, the sample of the experiment JL-1 is a dry powder mixture before the SMTZ-A in the experiment JL-2 reacts, the experiment reaction temperature is increased in the experiment JL-3, and the plugging material is added in the experiment JL-4Hydration experiment reaction time, no structural assistant J1 is added in experiment JL-5 and experiment JL-6, and no retarder HN1 is added in experiment JL-7 and experiment JL-8. As shown in Table 2, the reaction is mainly carried out by S1, and S1 is hydrated to produce a large amount of Na [ Al (OH) ] 4 ](HS 1), namely the main product is HS1, the S1 is basically completely reacted, only a few low-activity S1 do not participate in the hydration reaction, and the excitant and the retarder are almost not present in the solidification body after the hydration reaction.
Table 1: experimental design of hydration reaction mechanism
Table 2: ingredient list before and after hydration reaction
The composition of the sample phase can be analyzed using X-ray diffraction (XRD). The XRD analyzer adopts a physical DMAX-3C diffractometer, a CuKa working target and Ni filtering, the 2 theta is 5-70 degrees, the scanning step length is 0.02, and the scanning speed is 8 degrees/min. The product and microstructure of the hydrated slurry can be observed by a scanning electron microscope, and the elemental composition of the hydrated product can be determined by an energy spectrum diagram. And (3) drying the solidified body at a constant temperature of 60 ℃, exposing a fresh section, and carrying out microstructure analysis.
FIG. 5 shows a scanning electron micrograph of a sample obtained after SMTZ-A is maintained in distilled water at a constant temperature of 90 ℃ for 24 hours. A large number of thin crystal bodies and massive crystal bodies can be observed in the graph 5, a large number of more regular thin crystal bodies can be observed in the graph 6 to be attached to the edge of the massive crystal body to grow, the thin crystal bodies are cemented with the massive crystal bodies through the physical cementation capacity of the thin crystal bodies to form a whole body and show certain mechanical strength, and the thin crystal bodies form a 'clamping room' shaped three-dimensional structure through cross growth to further improve the structural strength of the cemented body. As shown in Table 3, it can be seen from the visual field A that the main elements of the bulk crystal are carbon, oxygen and calcium (key elements of the structural auxiliary), and calcium and oxygenThe proportion of the element is slightly less than 1:3, which shows that the main substance at the point is the structural auxiliary agent J1. The main elements of the flake crystal are oxygen element and aluminum element (key element of the solidification main agent) which are seen in the visual field B, the proportion of the aluminum element to the oxygen element is slightly less than 1:2 except the oxygen element amount occupied by other elements, and the main hydration product of the point is Na [ Al (OH) 4 ](HS 1), there may be a few S1 insufficiently reacted, consistent with the results of XRD analysis.
Table 3: the results of the energy spectrum analysis of the views A and B in FIG. 5
Fig. 6 shows the process of hydration of S1, and the curing reaction of SMTZ-a proceeds mainly through the hydration of the curing host S1. The curing main agent S1 adsorbs H through the surface + Dissolving and precipitating to form precipitated particles containing hydroxyl. H is adsorbed on the surface of the curing main agent S1 + And surface dissolution are key to influencing the rate of hydration reactions. In the original S1-H 2 In an O system, S1 hydration rate is slow, hydration product particles are dispersed, the crystal form is coated on the surface of unhydrated S1 in an amorphous manner to form a bulk S1-HS1 aggregate, and stable X is difficult to form in the S1-HS1 suspension liquid phase due to low solubility of HS1 2+ The difference in ion concentration promotes the growth of HS1 crystals, so HS1 having a plate-like crystal morphology cannot be formed, and thus a consolidated body having strength cannot be formed. After addition of activator M1, in S1-M1-H 2 In the O system, M1 provides X with high concentration and stability in liquid phase 2+ Ions, which provide stable S1 to the HS1 crystal surface 2+ The concentration difference promotes stable growth of HS1 crystals and the formation of a plate-like crystalline product. After adding the structural assistant J1, adding the structural assistant in the S1-J1-M1-H 2 In the O system, the cluster S1-HS1 aggregate generated by S1 through hydration reaction enables the structural auxiliary J1 particles to form a skeleton structure with certain strength at the initial stage, the exciting agent M1 can enhance the skeleton structure to a certain extent in the process of promoting S1 hydration reaction, and promotes S1 hydration reaction to generate the expandable substance HS1, so that the expandable substance HS1 can be filled between the structural auxiliary J1 particlesThe pore space of (2) further improves the stability of the framework structure and the overall strength of the consolidation body.
Table 4 shows the product composition after hydration of SMTZ-A in the presence or absence of a structure builder. In the absence of structural auxiliaries, the degree of reaction of S1 is significantly increased, and the hydration product remains HS1 unchanged. However, from experimental results, after the SMTZ-a hydration reaction without the structural assistant, the toughness of the consolidated body is reduced, the brittleness is obviously increased, the structural strength is reduced as a whole, which is unfavorable for the sealing of a leak layer by the cured material, which means that the structural assistant has the following influence on the curing reaction: the reaction product of the structural auxiliary agent and the curing main agent S1 is cemented to provide structural strength for the consolidated body.
Table 4: the product component after hydration of SMTZ-A in the presence or absence of a structural auxiliary
Table 5 shows the composition of the resultant after the reaction of the curing material in the presence or absence of the structure-forming assistant. Without the structural assistant, the degree of reaction of S1 is reduced to a small extent. Under the condition of no retarder, the position of the characteristic peak of the hydration product is unchanged, the strength of the characteristic peak is obviously increased, the hydration product is still HS1 without change, and the growth degree of the flake crystal is higher along with no retarder participating in the solidification reaction. However, from experimental results, after SMTZ-A hydration reaction without retarder, the toughness of the solidified body is increased, the structural strength is not changed integrally, and the method is favorable for sealing a leaking layer by the solidified material. The effect of the retarder on the hydration reaction is: the set retarder will reduce the crystallinity of the solidified main S1 reaction product but will not affect the structural strength of the consolidated body, which means that the effect of the set retarder on the hydration reaction is negligible.
Table 5: the substance component formed after the reaction of the curing material in the presence or absence of a structure-forming assistant
Table 6 shows the composition of the resultant materials at different reaction temperatures. The reaction temperature is increased, the reaction degree of S1 is improved, and the hydration product is still HS1 without change. This means that the hydration reaction of the curing base S1 is facilitated by raising the reaction temperature. FIG. 7 shows the SEM image of the sample after being maintained at 120 deg.C for 24 h. From the scanning electron micrograph, it can be seen that the growth conditions of the flake crystals HS1 and J1 are basically consistent with those of a control group after the reaction temperature is raised, but the extensibility of the flake crystals is obviously increased, the thickness of the flake crystals is obviously increased, the growth conditions are consistent with the analysis result of XRD, the flakes are nested with one another and are more compact, a three-dimensional 'cabin' -shaped three-dimensional structure is integrally presented, and the structural strength of a solidified body is further increased. The high-temperature hydrothermal environment reduces the viscosity of the solution, accelerates the movement speed of ions and reduces the activation energy of the reaction.
Table 6: ingredient list after hydration reaction at different reaction temperatures
Table 7 shows the composition of the resultant substances for various reaction times. The reaction time is increased, the reaction degree of S1 is slightly improved, and the hydration product is still HS1 without change. This means that increasing the reaction time facilitates the hydration reaction of the curing base S1. FIG. 8 shows a scanning electron micrograph of the sample after curing at a constant temperature of 90 ℃ for 48 hours. From the scanning electron micrograph, it can be seen that the growth conditions of the thin crystal HS1 and the thin crystal J1 after the reaction time is increased are basically consistent with those of the control group, but the thickness of the thin crystal is obviously increased, the whole grows obviously compared with the control group, the thin crystals are more compact in a nested manner, the whole presents a three-dimensional structure in a shape of a three-dimensional clamping room, and the structural strength of the consolidated body is further increased.
Table 7: ingredient list after hydration reaction under different reaction time
Example 2:
example 2 is a further development of example 1. The leaking stoppage drilling fluid comprises a leaking stoppage material and polysulfonate drilling fluid; wherein the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.3-0.5: 1. namely, in the using process, the weight ratio of the components is 0.3-0.5: 1, adding the plugging material into the polysulfonate drilling fluid to perform corresponding plugging.
The polysulfonate drilling fluid contains bentonite in a certain proportion, and the bentonite mainly contains clay minerals which mainly comprise montmorillonite, illite, kaolinite and the like. After the alkalinity is enhanced, the clay mineral is subjected to alkaline corrosion reaction under the combined action of strong alkalinity and high temperature to generate an aluminosilicate gelling system. Because the bentonite in the polysulfonate drilling fluid is fully hydrated, the granularity reaches micron level, the dispersibility is good, and the good reaction activity is achieved. Therefore, the gel system can be rapidly generated under the strong alkaline condition. The dual-gel system formed by the gel system and the gel system produced by the lost circulation material enables the concentration of the gel substance in the drilling fluid to meet the curing requirement in a short time, and creates favorable conditions for entering a leakage layer for curing.
The plugging material contains a high proportion of water-insoluble substances, and the solid phase content of the drilling fluid can be increased after the materials are doped into the polysulfonate drilling fluid, so that the quality of a filter cake of the drilling fluid is deteriorated, namely the permeability of the filter cake is obviously increased, and the macro expression shows that the filtration loss is obviously increased. In addition, after the bentonite reacts to generate a cementing material, clay sheets in the drilling fluid are gradually consumed, and a 'card-room' shaped grid structure of an original drilling fluid system is damaged to a certain extent, so that the rheological property and the filtrate loss reduction property of the drilling fluid are poor, and the filtrate loss of the drilling fluid is further increased. The increase of the filtration loss is beneficial to the drilling fluid entering a leaking layer for plugging, the high filtration loss can lead the drilling fluid to rapidly lose water on the wall surface of the crack, and solid-phase substances such as structural auxiliary agents in the drilling fluid are rapidly deposited in the crack, thus being beneficial to forming a high-strength plugging zone.
The plugging zone formed by the plugging material/the plugging drilling fluid can be removed by acid dissolution. The incompletely reacted metal oxide in the curing main agent, the acid-soluble component in the structural assistant, the residual excitant and the like are substances which are easy to react with the acid liquor. The acid liquor contacts with the solidified body, the acid liquor reacts with the acid-soluble part in the solidified body, the structure of the solidified body collapses in the reaction process, the plugging zone is removed, and a small amount of residual solid phase can be carried to the shaft through the backflow action of formation fluid, so that the aim of acid-soluble removal is finally achieved.
The polysulfonate drilling fluid comprises the following components in percentage by mass: 4% of bentonite and sodium carbonate (Na) 2 CO 3 ) 0.2 percent of sodium carboxymethylcellulose (CMC), 0.15 percent of sodium hydroxide (NaOH), 0.1 percent of potassium polyacrylamide (KPAM), 0.08 percent of polyanionic cellulose (PAC-LV), 3 percent of Sheet Molding Compound (SMC), 4 percent of sulfonated phenolic resin (SMP-1), 7 percent of potassium chloride (KCl) and the balance of water. Table 8 shows the above-described polysulfonate drilling fluid performance parameters.
Table 8: polysulfonate drilling fluid performance parameters
The SMTZ-A ratio of the drilling fluid mixed with the polysulfonate is different, and the performance of a consolidation body formed after static curing is also different. In order to ensure the effect of the SMTZ-A in curing the polysulfonate drilling fluid, experimental study is carried out on the doping amount of the SMTZ-A, under the condition that the conditions of reaction temperature, reaction time, single-agent ratio of the SMTZ-A (S1 (aluminum oxide): J1 (calcium carbonate) = M1 (sodium hydroxide) = 3), and the like are kept unchanged, the doping amount of the SMTZ-A doping polysulfonate drilling fluid is changed (sequentially increased from 10% to 50%), the polysulfonate drilling fluid doped with the SMTZ-A is filled into a standard circular cement paste mold after sealing treatment, and a sealing agent is used for sealing and marking a glass plate on the standard circular mold, wherein the specific experimental design is shown in Table 9.
Table 9: optimization experimental design of doping amount
After static maintenance is carried out on the polysulfonate drilling fluid doped with SMTZ-A at the constant temperature of 90 ℃ for 48 hours, a mold filling sample is taken out from a constant-temperature water bath kettle, and a solidified body sample after drying and removing the mold is shown in figure 9. After the CR-1 and CR-2 samples are statically maintained at constant temperature for 48 hours, a solidified body formed by the samples is obviously reduced, the surface of the CR-1 sample has a plurality of holes, the compactness is poor, the holes on the surface are many, and the appearance is dark brown; the surface of the CR-2 sample has more holes, the compactness is obviously better than that of the CR-1 sample, and the appearance is brown; the solidified bodies formed by the CR-3, CR-4 and CR-5 samples have small volume change, fewer holes and better compactness, and the color of the solidified bodies is gradually changed from the color similar to polysulfonate drilling fluid to the color of SMTZ-A slurry from the appearance observation of the samples.
The upper bottom diameter R, the lower bottom diameter R and the height h of the consolidation body are respectively measured for 3 times by using a vernier caliper, and the average value is obtained through the following formulas:
the volume V of the solidification body and the shrinkage thereof were calculated, and the measurement results are shown in Table 10, and the relationship between the shrinkage of the solidification body and the incorporation amount of SMTZ-A is shown in FIG. 10.
Table 10: experimental result of influence of SMTZ-A doping amount on solidification body shrinkage rate
Table 10 shows the shrinkage and cure time of the consolidated bodies. It can be seen from the table that when the amount of the SMTZ-A is less than 30%, the curing time is much longer than 24h, and when the amount of the SMTZ-A is more than 30%, the curing time is about 2h, which meets the requirement of plugging. Fig. 10 shows a tendency that the shrinkage of the consolidated body shows a gradual decrease as the SMTZ-a incorporation amount increases. When the doping amount of the SMTZ-A is 10 percent and 20 percent, the shrinkage rate of a consolidation body is larger, mainly because the doping amount of the SMTZ-A is smaller, the particles of the plugging material in the slurry are distributed in the slurry in a dispersing way, the distance of different single-agent particles is longer, in the process of a curing reaction, aggregation and curing reaction occur among the particles of the plugging material to form larger particles, the sedimentation phenomenon occurs, and the aggregation and curing reaction further occurs, so that the shrinkage rate of the consolidation body is larger. In the process of 10% to 30%, the shrinkage rate of the solidification body is obviously reduced, when the doping amount of the SMTZ-A reaches 30%, the shrinkage rate is reduced to 3.02%, after the doping amount is further increased, the shrinkage rate of the solidification body is further reduced, the shrinkage rate is 0.38%, when the doping amount reaches 50%, the solidification body is expanded, and the formed solidification body expands to a certain extent relative to the volume of the SMTZ-A after the SMTZ-A is subjected to a curing reaction. It is preliminarily determined from the shrinkage that the amount of incorporation of SMTZ-A should be at least more than 30%, and the curing effect becomes more pronounced as the amount of incorporation of SMTZ-A increases. Therefore, in the embodiment, the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.3-0.5: 1 is fully feasible and 0.4:1.
fig. 11, 12 and 13 show the relationship between the curing time and the addition amount of a retarder including at least one of sodium borate, sodium gluconate and sodium phosphate under the quantitative condition of the plugging material. Under the condition that the doping amount of the plugging material is 30%, the curing time integrally shows an upward trend along with the increase of the addition amount of the retarder. Under the conditions of high temperature of 90 ℃ and pressure of 50MPa, when the addition amount of the retarder is small, the delayed curing effect of the retarder is not obvious, the curing time increasing amplitude is obviously increased along with the gradual increase of the retarder, and the delayed curing effect of the retarder is more obvious. Meanwhile, under different doping amounts of the plugging material and the addition amount of the retarder, the change amplitude of the initial setting time and the final setting time is basically kept consistent. Under the condition that the doping amount of the plugging material is 40% and 50%, the same experimental result can be obtained, which shows that the retarder has the addition adjustability. The curing time can be controlled in a reasonable range by adjusting the dosage of the plugging material and the retarder in the SMTZ-A. And as can be seen from fig. 12 to 14, when the mass ratio of the retarder to the plugging material is more than 10%, the curing time is further increased to 200min, which can meet the basic requirements of field application; when the addition amount of the retarder reaches 13.3%, the setting time of the slurry can still be increased to 370min. Under the experimental condition, the curing time and the addition amount of the retarder present a positive correlation, and the curing effect of the solidification body under different addition amounts of the retarder is better than that without the retarder, so that the curing time of the slurry can be adjusted by adding at least 10% of the retarder under the condition that the formation temperature is 90 ℃.
FIG. 15 shows the relationship between the slurry curing time and the retarder addition amount under the conditions that the plugging material incorporation amount is 40%, the experimental temperature is 120 ℃ and the experimental pressure is 60 MPa. Under the condition that the addition amount of the retarder reaches 20%, the curing time is only 86min, so that the addition amount gradient of the retarder is increased to 4%; when the addition of the retarder reaches 24%, the curing time is increased to 147min, and the requirements of field application are difficult to meet; when the addition of the retarder reaches 28%, the slurry curing time is greatly increased to 282min, and the requirements of field application can be met; when the addition amount of the retarder reaches 32%, the slurry solidification time is still greatly increased to reach 405min. Under the experimental condition, the curing time and the addition amount of the retarder are in positive correlation, and the curing effect of the solidification body under different addition amounts of the retarder is better than that of the solidification body without the retarder, so that the curing time of the slurry can be still adjusted by the addition amount of the retarder when the doping amount of the plugging material is 40% under the condition that the formation temperature is 120 ℃, and a larger addition amount of the retarder is required under the conditions that the experimental temperature is 90 ℃ and the experimental pressure is 50 MPa. The mass ratio of the retarder to the plugging material can be selected from 0.1-0.4: 1, in the extreme case, 0.3:1.
in the specific implementation process, the good rheological property of the polysulfonate drilling fluid doped with the SMTZ-A is the premise of safe construction, so that the influence of the SMTZ-A on the rheological property of the polysulfonate drilling fluid is the primary consideration in the performance of all drilling fluids, and in addition, in the plugging operation, the SMTZ-doped polysulfonate drilling fluid is required to have good thixotropy besides the basic performance relative to the polysulfonate drilling fluid. And measuring and calculating the apparent viscosity, plastic viscosity, dynamic shear force, initial shear force and final shear force of the SMTZ-A polysulfonate doped drilling fluid.
Figure 16 shows polysulfonate drilling fluid rheology versus SMTZ-a incorporation. After SMTZ-A is doped into the polysulfonate drilling fluid, the apparent viscosity and the plastic viscosity of slurry are greatly reduced, and the dynamic shear force is obviously improved, because an excitant M1 in the SMTZ-A can cause molecular chain curling to a polymer, so that the gel protection effect of the polymer is damaged, the released cations can also compress a clay particle double electric layer in the drilling fluid, so that the colloid stability of bentonite is poor, and under the comprehensive action, the macroscopic expression is that the apparent viscosity and the plastic viscosity of the polysulfonate drilling fluid are reduced; with the increase of the SMTZ-A doping amount, the change trend of the apparent viscosity and the plastic viscosity of the polysulfonate drilling fluid doped with the SMTZ-A tends to be gentle after sharp increase, and the dynamic shear force increases after reduction, because the increase of the SMTZ-A doping amount causes the solid content in the slurry to increase, and then the apparent viscosity and the plastic viscosity are increased. It is noted that within the range of 30% -50% SMTZ-A incorporation, the viscosity of the slurry is close to the initial viscosity of the polysulfonate drilling fluid.
Figure 17 shows the relationship of polysulfonate drilling fluid fluidity index and consistency factor with SMTZ-a incorporation. After the polysulfonate drilling fluid is doped into the SMTZ-A, the fluidity index of the polysulfonate drilling fluid is obviously reduced, and the consistency coefficient is obviously improved, because the exciting agent M1 in the SMTZ-A enhances the net rack structure in a drilling fluid system, so that the fluidity index is reduced, and the consistency coefficient is improved. With increasing SMTZ-A incorporation, the fluidity index increased first and then decreased slightly, and the consistency index decreased first and then increased slightly, probably due to a combination of the swelling of the structure aid by hydration and the increase in the solids content. With the incorporation of SMTZ-A, the fluidity index is kept below 1 as a whole, which indicates that the polysulfonate drilling fluid has good shear thinning performance. The consistency coefficient is always kept between 0.04 and 0.5 Pa.s n The fact shows that the polysulfonate drilling fluid has small consistency and good pumpability under dynamic conditions.
FIG. 18 shows the relationship of polysulfonic drilling fluid thixotropy with SMTZ-A incorporation. With the increase of the doping amount of the SMTZ-A, the thixotropy (initial/final shear force difference) of the polysulfonate drilling fluid is increased and then tends to be gentle, because the addition of the exciting agent M1 in the SMTZ-A can improve the concentration of inorganic electrolyte in the polysulfonate drilling fluid, the flocculation degree of the drilling fluid is increased, and the difficulty in recovering a space grid structure in a polysulfonate drilling fluid system is increased, so that the thixotropy of the polysulfonate drilling fluid is obviously increased, and the thixotropy of the polysulfonate drilling fluid system is increased along with the increase of the doping amount of the SMTZ-A, which means that the polysulfonate drilling fluid doped with the SMTZ-A can be thickened quickly after the shear force of the polysulfonate drilling fluid entering a leaking layer is reduced, and is favorable for staying in the leaking layer during plugging.
In the specific implementation process, a laboratory self-made steel core is selected to simulate a natural fracture to perform plugging and pressure-bearing performance test on the plugging drilling fluid. The specification of the rigid core is a semi-cylinder with the diameter of 25mm and the length of 50mm, and in order to prevent abnormal dislocation of the core in the loading process, two semi-cylinders need to be tightly wrapped by transparent adhesive tapes. And selecting a shale core without cracks observed by naked eyes to simulate induced cracks. Utilize the wire-electrode cutting door window to open the rock core along the axis direction, use metallographic abrasive paper to polish the section, use narrow steel sheet pad around polishing face edge, compress tightly and use scotch tape to wrap up firmly fixedly, make the crack rock specimen that has fixed width. The thickness of the copper sheet to be padded determines the width of the crack, and the specification of a single copper sheet adopted in the experiment is as follows: the thickness is about 1mm and the width is about 2mm. The test results are shown in table 11.
Table 11: test result of pressure bearing capacity of leaking stoppage drilling fluid
Because the plugging zone of the reservoir section needs to be removed by means of acid dissolution, self-degradation and the like, the plugging zone formed by the plugging drilling fluid is subjected to plugging removal performance (reservoir protection performance) test. The acid dissolution test comprises two parts of contact acid dissolution and immersion acid dissolution. The preparation method of the immersion type acid-soluble experimental sample comprises the following steps: curing the 40 percent SMTZ-A doped polysulfonate drilling fluid slurry at the constant temperature of 90 ℃ for 24h, taking out the slurry, and crushing the solidified body into small blocks. The preparation method of the contact acid soluble experimental sample comprises the following steps: the polysulfonate drilling fluid slurry mixed with 40 percent of SMTZ-A is injected into a homemade fixed seam width (2.00 mm and 6.00 mm) rigid core which is wrapped and fixed by a transparent adhesive tape, and is taken out and carefully removed after being maintained for 24 hours at the constant temperature of 90 ℃ and the upper end of the core is sealed.
The acid dissolution test (hydrochloric acid concentration is 15%) is divided into two parts of soaking type acid dissolution test and contact type acid dissolution test, wherein the soaking type acid dissolution test sample is a preferable regular solidified body, 10g of fragments of edges and corners are cut by a knife, and the contact type acid dissolution test plugging band is obtained by solidifying slurry in a steel rock core column with the seam width of 2.0mm and 6.0 mm. The results of the immersion-type acid dissolution test are shown in fig. 19, and the results of the contact-type acid dissolution test are shown in fig. 20. It can be seen that the plugging formed by the plugging drilling fluid has excellent plugging removal performance (reservoir protection performance).
Figure 21 shows the effect of SMTZ-a incorporation on polysulfonic drilling fluid density. When the SMTZ-A ratio of the doped polysulfonate drilling fluid is respectively 30 percent, 40 percent and 50 percent, the density of the slurry respectively reaches 1.19g/cm 3 、1.26g/cm 3 And 1.32g/cm 3 . The density of the polysulfonate drilling fluid is in positive correlation with the doping amount of the SMTZ-A, because the density of the SMTZ-A is far larger than that of the polysulfonate drilling fluid, and the solid content is increased along with the doping of the SMTZ-A, so that the density of the polysulfonate drilling fluid is increased. After the SMTZ-A is doped into the polysulfonate drilling fluid, the linear relation between the slurry density and the SMTZ-A doping amount is realized, and the good addition adjustability of the SMTZ-A on the density of the polysulfonate drilling fluid is proved.
Because the well depth of the loss is different and the formation pressure is different in the drilling process, the density of the polysulfonate drilling fluid doped with SMTZ-A has larger adjustability to meet different pressure gradients. The density of the polysulfonate drilling fluid slurry doped with SMTZ-A can be adjusted by using a density regulator mature on site, such as hollow microspheres, barite, hematite powder and the like. The density adjustment test examined the density adjustment range of the slurry without affecting the curability and the curing strength of the slurry, and table 12 shows specific density modifiers, the addition amounts thereof, and the test results.
Table 12: SMTZ-A doped polysulfonate drilling fluid density adjustment experimental design and result
From the experimental results, addThe density of the density regulator added with barite, hollow micro-beads and the like can be between 0.8 and 2.0g/cm 3 Secondary adjustment is performed within the range. Up to 20% additions of cenospheres and 40% additions of barite, which have little effect on the solidifiability and the setting strength of the slurries, were achieved in the density adjustment experiments. With the great increase of the addition of the density regulator, the consolidated body shows more pores, micro cracks and even large cracks.
Fig. 22 and 23 show particle size distribution profiles for SMTZ-a drilling fluids. At a doping level of 30%, D10=0.877 μm, D50=10.39 μm, D90=54.35 μm; when the doping amount is 50%, D10=0.853 μm, D50=10.46 μm, and D90=54.42 μm. After the SMTZ-A is doped into the polysulfonate drilling fluid, the slurry D10, D50 and D90 are slightly increased, the overall change is not obvious, the particle size distribution of the SMTZ-A is close to the particle size distribution of the drilling fluid, and the influence of the SMTZ-A on the particle size distribution of the polysulfonate drilling fluid is small. The D90 of the polysulfonate drilling fluid doped with SMTZ-A is about 55 mu m, and the plugging to the leakage layer with micron and above scales can be realized. The D50 and D90 values of the plugging material in the patent mentioned in the background art are 15.0 μm and 50.8 μm respectively, which shows that the slurry of the plugging material can enter the micron-sized and above-width cracks of the stratum for plugging.
In order to clarify the strength change condition of the SMTZ-A solidified polysulfonate drilling fluid, the strength change of the slurry of the polysulfonate drilling fluid doped with the SMTZ-A after solidification is characterized by using the penetration instead of the compressive strength, and the strength change mainly comprises the initial strength (at final setting), the final strength (no change occurs from final setting to strength) and the strength development process (after final setting) of the slurry.
Fig. 24 shows the strength of slurry curing as a function of the amount of lost circulation material (curing agent) incorporated. The solidification strength of the polysulfonate drilling fluid slurry doped with the SMTZ-A is closely related to the doping amount of the plugging material. When the mixing amount of the SMTZ-A is respectively 30-50%, the early penetration degree (final setting) of the slurry thickened to form a solidified body is respectively 29mm, 26mm and 21mm, and the final penetration degree (after curing for 48 h) is respectively 5mm, 4mm and 3mm. It is shown that as the amount of the curing agent incorporated increases, both the early strength and the final strength increase, and at the same time, the cured body becomes drier and the strength develops more rapidly. By comparing the penetration curves of 40% curing agent cured water and the polysulfonate drilling fluid, the early strength of a consolidated body obtained by curing the polysulfonate drilling fluid by the SMTZ-A is obviously reduced, and the final strength is reduced to some extent, macroscopically, the concentration of the SMTZ-A is increased due to the fact that the SMTZ-A is settled to a certain extent in the water, so that the structural strength of the consolidated body is improved, and microscopically, the fact that the polysulfonate drilling fluid has a certain influence on the curing reaction can be known.
In the specific implementation process, the preparation process of the plugging drilling fluid can be as follows:
1) Determining the amount of the curing leaking stoppage slurry required to be prepared according to the leaking stoppage scheme, selecting a proper slurry tank and cleaning;
2) Calculating the dosage of the leaking stoppage material and the retarder which need to be doped according to the dosage of the solidified leaking stoppage slurry;
3) Preferentially adding a quantitative exciting agent into the polysulfonate drilling fluid, fully stirring for at least 30min, and standing for a period of time after uniform stirring due to the large consumption and slow heat dissipation of the required solidified plugging slurry;
4) After the activator is completely dissolved, adding the retarder, and fully stirring for about 10min;
5) Adding a curing main agent and a structural auxiliary agent, and fully stirring for more than 10min to ensure that the mixture is uniformly mixed with the polysulfonate drilling fluid;
6) After the plugging slurry (the plugging drilling fluid) is successfully prepared, calcium carbonate particles can be added, and the mixture is stirred for 10min to obtain the synergistic plugging slurry (the synergistic plugging drilling fluid).
In the specific implementation process, the on-site leaking stoppage construction steps can be as follows:
1) Preparing for plugging: the drilling tool for plugging the drill pipe is pulled out, the drilling tool is lowered to 50m above a leaking layer, and the leakage speed is measured in a circulating mode;
2) Preparing slurry on site: designing and preparing a proper amount of (synergistic) plugging slurry according to the actual conditions of the lost circulation;
3) Injecting and replacing plugging slurry: accurately calculating the displacement mud amount, and taking out the drill bit to be above a safe liquid level according to the height of the surface of the leaking stoppage slurry after the (synergistic) leaking stoppage slurry is replaced;
4) Removing the drill pipe and waiting for plugging: after the displacement is finished, the drill is pulled out to a safe well section or a casing pipe, the front columns are as slow as possible, the backflow of plugging slurry caused by swabbing is prevented, and the high-concentration (synergistic) plugging slurry is avoided in a drilling tool and the annulus; standing for 8-12 h; the mud tank and the pipeline are cleaned in time during the plugging waiting period, so that the equipment is prevented from being plugged by (synergistic) plugging mud.
5) Drilling and plugging checking: and (3) removing the drill, replacing the drill, drilling the drill plug, circulating in sections during the drilling, determining the plug surface when meeting the blockage, and drilling the plug. And (4) the drilling plug is drilled without leakage in a normal discharge circulation mode, the drilling is recovered, if the drilling fluid density needs to be improved in the lower construction, a pressure bearing test is carried out, and the drilling is recovered after the requirement is met. If the leakage or the pressure bearing capacity is insufficient, the leakage stopping formula and the scheme are optimized, and the leakage stopping construction is continued.
The plugging method and the construction steps do not need to prepare slurry in advance, so that the construction time is saved; additional fluid does not need to be prepared, so that the material cost is saved; the storage is convenient on site, and the use is convenient; the problem of slurry pollution is avoided, and the construction risk caused by pollution is eliminated.
In summary, the use of the plugging material SMTZ-a has the following 4-point advantages for natural fracture loss:
(1) The SMTZ-A particle size distribution is slightly larger than the polysulfonate drilling fluid on the whole, so that the polysulfonate drilling fluid doped with the SMTZ-A can enter the SMTZ-A particle size distribution at any place where the polysulfonate drilling fluid is lost, and the width of a crack does not need to be identified;
(2) The retention capacity is strong. The polysulfonate drilling fluid doped with more than 30% of SMTZ-A has strong thixotropy, and the slurry can be thickened quickly after entering a natural fracture channel so as to stay in a leakage layer; meanwhile, because the API filtration loss and the thickness of a filter cake are large, the slurry can be rapidly filtered after entering a natural fracture channel, and SMTZ-A and solid-phase substances are rapidly precipitated, enriched and compacted, so that the rate of forming a compact plugging zone by curing the polysulfonate drilling fluid by the SMTZ-A is accelerated;
(3) The bearing capacity is high. The pressure-bearing capacity of a plugging belt formed by doping 40% of SMTZ-A into the polysulfonate drilling fluid to a natural crack with a crack width of 4.0mm exceeds 10MPa, and the pressure-bearing capacity can be further improved after calcium carbonate particles are used for synergetic plugging. In addition, after the slurry is subjected to filtration loss in a leakage passage, the SMTZ-A doping amount in the polysulfonate drilling fluid is increased in a phase-changing manner, so that the pressure bearing capacity of the plugging zone is further improved;
(4) Can be dissolved in acid to block. The solidification body obtained by doping SMTZ-A into the polysulfonate drilling fluid has high acid dissolution speed and high acid dissolution rate in 15% hydrochloric acid, and can effectively relieve the damage of crack permeability caused by plugging materials.
Aiming at induced crack loss, the leaking stoppage material SMTZ-A has the following 4-point advantages:
(1) The SMTZ-A particle size distribution is close to that of the polysulfonate drilling fluid, the adaptability to cracks with different scales is strong, and the induced crack width does not need to be identified;
(2) 0% incorporation D90=54.42 μm for SMTZ-a polysulfonate drilling fluids, the particle size of SMTZ-a and drilling fluid solid phase is small and does not prevent induced fracture closure;
(3) The bearing capacity is high. 40 percent of the pressure-bearing capacity of the plugging zone formed by mixing the SMTZ-A and the ceramsite into the polysulfonate drilling fluid to an induced crack with the seam width of 3.0mm exceeds 14MPa, and after the slurry is subjected to filtration loss in a leakage passage, the mixing amount of the SMTZ-A in the polysulfonate drilling fluid is improved in a phase-changing manner, so that the pressure-bearing capacity of the plugging zone can be further improved;
(4) After plugging removal, the fracture can be supported. When the ceramic particle is applied to induced fracture reservoirs, the acid solubility of a solidified body obtained by mixing SMTZ-A and ceramic particles into the polysulfonate drilling fluid in 15% hydrochloric acid is high, the ceramic particle breakage rate is low, and after the solidified and blocked solid is dissolved with acid, the ceramic particles can support induced fractures to provide seepage channels for oil and gas resources.
Aiming at stratum loss of a fractured zone, the plugging material SMTZ-A has the following 3 advantages:
(1) The retention capacity is strong. The polysulfonate drilling fluid doped with more than 30% of SMTZ-A has strong thixotropy and good API (American Petroleum institute) filtration property, slurry can be thickened quickly after entering a stratum leakage channel of a fractured zone to stay in a leakage layer, the slurry can be filtered quickly after entering the stratum leakage channel of the fractured zone, and the SMTZ-A and solid-phase substances are precipitated, enriched and compacted quickly, so that the rate of forming a compact plugging zone by the SMTZ-A solidified polysulfonate drilling fluid is accelerated;
(2) The bearing capacity is high. The pressure-bearing capacity of a plugging belt formed by doping 40% of SMTZ-A into the polysulfonate drilling fluid to a natural crack with a crack width of 4.0mm exceeds 10MPa, and the pressure-bearing capacity can be further improved after calcium carbonate particles are used for synergetic plugging. In addition, after the slurry is subjected to filtration loss in a leakage passage, the SMTZ-A doping amount in the polysulfonate drilling fluid is increased in a phase-changing manner, so that the pressure bearing capacity of the plugging zone is further improved;
(3) The performance is adjustable. The stratum retention capacity and the plugging pressure-bearing capacity can be enhanced by adjusting the doping amount according to the requirement of the stratum in a fractured zone.
Claims (12)
1. The plugging material is characterized by comprising the following components in percentage by mass: 52 to 64 percent of curing main agent, 20 to 30 percent of structural assistant and 14 to 18 percent of excitant.
2. The lost circulation material of claim 1, wherein the mass ratio of the curing main agent to the structural assistant to the activator is 7:3:2.
3. lost circulation material according to claim 1 or 2, wherein the curing host comprises at least one of alumina, fly ash and silica.
4. Lost circulation material according to claim 1 or 2, wherein the activator comprises at least one of sodium hydroxide, potassium hydroxide, sodium carbonate and lime powder.
5. Lost circulation material according to claim 1 or 2, wherein the structural aids comprise at least one of calcium carbonate powder, quartz powder, magnesium hydroxide and inert bridging materials.
6. A lost circulation drilling fluid comprising the lost circulation material of any one of claims 1 to 5, characterized by comprising a polysulfonate drilling fluid; wherein the mass ratio of the plugging material to the polysulfonate drilling fluid is 0.3-0.5: 1.
7. the plugging drilling fluid as claimed in claim 6, wherein the mass ratio of the plugging material to the polysulfonic drilling fluid is 0.4:1.
8. lost circulation drilling fluid according to claim 6 or 7, further comprising a retarder; wherein the mass ratio of the retarder to the plugging material is 0.1-0.4: 1.
9. the leaking stoppage drilling fluid according to claim 8, wherein the retarder comprises at least one of sodium borate, sodium gluconate and sodium phosphate, and the mass ratio of the retarder to the leaking stoppage material is 0.3:1.
10. a preparation method of a leaking stoppage drilling fluid comprises the leaking stoppage material of any one of claims 1 to 5, and is characterized by comprising the following steps:
a1, determining the dosage of the curing leaking stoppage slurry required to be prepared according to a leaking stoppage scheme;
a2, calculating the dosage of the leaking stoppage material and the retarder which need to be doped according to the dosage of the solidified leaking stoppage slurry;
a3, adding an exciting agent into the polysulfonate drilling fluid, fully stirring for at least 30min, and standing until the exciting agent is completely dissolved;
a4, adding a retarder, and fully stirring for at least 10min;
and A5, adding the curing main agent and the structural auxiliary agent, and stirring until the curing main agent and the structural auxiliary agent are uniformly mixed with the polysulfonate drilling fluid to finish the preparation of the plugging drilling fluid.
11. The method for preparing a lost circulation drilling fluid according to claim 10, wherein the method further comprises the following steps after the step A5:
and A6, adding calcium carbonate particles, and stirring for at least 10min.
12. A lost circulation method comprising the lost circulation material of any one of claims 1 to 5, characterized by comprising the following steps:
b1, plugging preparation: the drilling tool for plugging the drill pipe is pulled out, the drilling tool is lowered to 50m above a leaking layer, and the leakage speed is measured in a circulating mode to obtain the actual condition of the well leakage;
b2, field slurry preparation: determining the quantity of the required solidified plugging slurry according to the actual conditions of the lost circulation and preparing the plugging drilling fluid;
b3, replacing plugging slurry by injection: calculating the amount of displacement mud, and taking out the drill according to the height of the liquid level of the leaking stoppage drilling fluid until the displacement is finished after the leaking stoppage drilling fluid is displaced into the drilling fluid;
b4, tripping waiting for plugging: the well is pulled out to a safe well section or a casing pipe, and the well is static for 8 to 12 hours;
b5, drilling, plugging and checking: removing the drill, replacing the drilling tool, drilling down to detect the plug, circulating in sections during the drilling down, determining the plug surface when meeting the plug, and drilling the plug;
and B6, when the normal discharge circulation is not leaked after the drilling and plugging, the drilling is resumed to finish the plugging.
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| CN202211193216.5A CN115491185A (en) | 2022-08-08 | 2022-09-28 | Plugging material, plugging drilling fluid, preparation method of plugging drilling fluid and plugging method |
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| US7297664B2 (en) * | 2004-07-28 | 2007-11-20 | Halliburton Energy Services, Inc. | Cement-free zeolite and fly ash settable fluids and methods therefor |
| CN102994057B (en) * | 2012-12-12 | 2016-09-07 | 中国石油化工股份有限公司 | A kind of temperature-resistant anti-salt profile control agent and preparation method thereof |
| RU2635413C2 (en) * | 2013-09-09 | 2017-11-13 | Халлибертон Энерджи Сервисез, Инк. | Cement setting activators for cement compositions and corresponding methods |
| CN106318347A (en) * | 2015-06-15 | 2017-01-11 | 中石化石油工程技术服务有限公司 | Silicate-aluminate anti-sloughing drilling fluid |
| CN105349125A (en) * | 2015-10-26 | 2016-02-24 | 中国石油天然气集团公司 | Pressure bearing and leakage blocking agent |
| CN110734752B (en) * | 2018-07-18 | 2022-10-14 | 中石化石油工程技术服务有限公司 | Plugging agent and preparation method thereof |
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