CN116987490A - Drilling fluid 3T treating agent and application method thereof - Google Patents
Drilling fluid 3T treating agent and application method thereof Download PDFInfo
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- CN116987490A CN116987490A CN202310977313.1A CN202310977313A CN116987490A CN 116987490 A CN116987490 A CN 116987490A CN 202310977313 A CN202310977313 A CN 202310977313A CN 116987490 A CN116987490 A CN 116987490A
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- 238000005553 drilling Methods 0.000 title claims abstract description 116
- 239000012530 fluid Substances 0.000 title claims abstract description 107
- 238000000034 method Methods 0.000 title claims abstract description 21
- 229920002678 cellulose Polymers 0.000 claims abstract description 68
- 239000001913 cellulose Substances 0.000 claims abstract description 68
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 67
- 230000035699 permeability Effects 0.000 claims abstract description 19
- 238000011282 treatment Methods 0.000 claims abstract description 18
- 239000002245 particle Substances 0.000 claims description 7
- 235000009496 Juglans regia Nutrition 0.000 claims description 3
- 238000000227 grinding Methods 0.000 claims description 3
- 238000002156 mixing Methods 0.000 claims description 3
- 230000002265 prevention Effects 0.000 claims description 3
- 238000012216 screening Methods 0.000 claims description 3
- 230000000087 stabilizing effect Effects 0.000 claims description 3
- 235000020234 walnut Nutrition 0.000 claims description 3
- 240000007049 Juglans regia Species 0.000 claims 1
- 239000002002 slurry Substances 0.000 description 26
- 239000004576 sand Substances 0.000 description 15
- 238000002474 experimental method Methods 0.000 description 8
- 229920000642 polymer Polymers 0.000 description 6
- 230000000903 blocking effect Effects 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- 230000000694 effects Effects 0.000 description 4
- 238000011156 evaluation Methods 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 239000003350 kerosene Substances 0.000 description 4
- 239000002105 nanoparticle Substances 0.000 description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 4
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- 239000000706 filtrate Substances 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 241000758789 Juglans Species 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 238000001914 filtration Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 238000011085 pressure filtration Methods 0.000 description 2
- 238000005728 strengthening Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000011149 active material Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 229920006317 cationic polymer Polymers 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000011109 contamination Methods 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 239000012065 filter cake Substances 0.000 description 1
- 238000005755 formation reaction Methods 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000012528 membrane Substances 0.000 description 1
- 239000000693 micelle Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000020477 pH reduction Effects 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000012779 reinforcing material Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 231100000048 toxicity data Toxicity 0.000 description 1
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
- C09K8/02—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
- C09K8/42—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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/514—Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B33/138—Plastering the borehole wall; Injecting into the formation
-
- 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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/04—Hulls, shells or bark containing well drilling or treatment fluids
Abstract
The invention discloses a drilling fluid 3T treatment agent and a use method thereof, belonging to the technical field of drilling fluids, and comprising millimeter-sized cellulose, micron-sized cellulose and nanometer-sized cellulose, wherein the millimeter-sized cellulose is divided into 1 millimeter-sized cellulose and 2 millimeter-sized cellulose, the proportion of the 1 millimeter-sized cellulose is 15%, the proportion of the 2 millimeter-sized cellulose is 30%, the proportion of the micron-sized cellulose is 20%, and the proportion of the nanometer-sized cellulose is 35%. According to the drilling fluid 3T treating agent with the structure and the application method thereof, the characteristics of a compact and thin plugging layer can be formed on a well wall by utilizing the drilling fluid 3T treating agent, so that the bearing force of the well wall is improved, the permeability of the well wall is reduced, and the drilling speed, the well cementation quality and the oil-gas well yield are further improved.
Description
Technical Field
The invention relates to the technical field of drilling fluid, in particular to a drilling fluid 3T treating agent and a using method thereof.
Background
The existing known well wall strengthening treatment agents at home and abroad are mostly composed of inert materials and polymers, and have some problems in field practical application, firstly, the well wall strengthening effect is not obvious, and the bearing capacity is insufficient; secondly, the plugging film still has a certain degree of permeability; thirdly, partial products have poor compatibility with slurry, and the rheological property of the drilling fluid is affected.
When conventional drilling fluid drills, when drilling is performed on formations such as high Kong Gaoshen loose sandstone, pressure failure, crack development, breakage or weak cementation, low permeability, deep well long open hole large section complex shale, multiple sets of pressure layers and the like, complex conditions such as differential pressure drilling sticking, drilling fluid leakage, well wall collapse, hydrocarbon reservoir damage and the like often occur.
Aiming at the problems on site, a novel well wall reinforcing material, namely a drilling fluid 3T treating agent, needs to be developed through mechanism analysis and material optimization on the basis of a large number of indoor experiments, so that the drilling speed, the well cementation quality and the oil and gas well yield are improved.
Disclosure of Invention
The invention aims to provide a drilling fluid 3T treating agent and a using method thereof, which utilize the characteristic that the drilling fluid 3T treating agent can form a compact and very thin blocking layer on a well wall, improve the bearing capacity of the well wall, reduce the permeability of the well wall and further improve the drilling speed, the well cementation quality and the oil and gas well yield.
In order to achieve the above object, the present invention provides a drilling fluid 3T treatment agent, comprising millimeter-sized cellulose, micron-sized cellulose and nano-sized cellulose, wherein the millimeter-sized cellulose is divided into 1 millimeter-sized cellulose and 2 millimeter-sized cellulose, the proportion of the 1 millimeter-sized cellulose is 15%, the proportion of the 2 millimeter-sized cellulose is 30%, the proportion of the micron-sized cellulose is 20%, and the proportion of the nano-sized cellulose is 35%.
The using method of the drilling fluid 3T treating agent comprises the following steps:
step 1: grinding and screening cellulose to obtain 1 millimeter cellulose, 2 millimeter cellulose, micron-sized cellulose and nanometer-sized cellulose respectively;
step 2: for 1 mm cellulose, 2 mm cellulose, micron cellulose and nanoscale cellulose according to 3:6:4:7, proportioning by weight ratio to obtain a drilling fluid 3T treating agent;
step 3: the drilling fluid 3T treating agent is uniformly mixed with the drilling fluid and then used according to the conventional use method of the drilling fluid under the condition that the positive pressure difference is not higher than the fracture pressure of the stratum.
Preferably, the 3T treating agent for drilling fluid is used for leakage prevention and blocking of low, medium and high permeability stratum and microcrack stratum, stabilizing well wall and improving the compression strength of stratum, and the mixing ratio of the 3T treating agent for drilling fluid and the drilling fluid is 0.3-3.0%.
Preferably, when the drilling fluid 3T treating agent is used for plugging small karst cave and large-crack stratum, the treating agent is firstly used by being matched with large-particle bridging particles such as walnut shells and the like according to the requirement, and then the treating agent and the drilling fluid are uniformly mixed according to the mass ratio of 3% -5% of the drilling fluid, and then the treating agent and the drilling fluid are used according to the conventional use method of the drilling fluid.
Therefore, the drilling fluid 3T treating agent adopting the structure and the using method thereof have the following advantages
The beneficial effects are that:
1. can be directly added into various types of drilling fluids without affecting the rheological property of the drilling fluids.
2. The drilling fluid 3T treating agent can form a compact and thin blocking layer on the well wall, improve the compressive strength of the well wall, reduce the permeability of the well wall, improve the drilling speed, the well cementation quality and the oil-gas well yield, and effectively reduce the well diameter expansion rate.
3. The drilling fluid with the drilling fluid 3T treating agent has the advantages that the plugging layer is formed quickly and thinly, mud cakes with the thickness of less than 4mm can be formed on a sand bed within 1 minute, the mud cakes have little thickness change along with the time, are only positioned on the surface of the rock, cannot penetrate into the depth of the rock, can effectively avoid differential pressure of the mud cakes and stuck drilling, and reduce the technical sleeve depth; the plugging layer (membrane) has strong bearing capacity, improves the leakage pressure and the cracking pressure gradient, enlarges the safety density window, and can better solve the technical problems of leakage, drill sticking, collapse, oil layer damage and the like of a long-naked-eye multi-set pressure layer or a pressure failure stratum.
4. The plugging layer formed by the drilling fluid added with the drilling fluid 3T treating agent can automatically fall off under the condition of negative pressure difference, can also be plugged by adopting methods of acidification, perforation and the like, has a filter cake clearance rate of more than 95%, has a permeability recovery value of more than 90%, and is favorable for protecting hydrocarbon reservoirs and improving hydrocarbon yield.
5. The drilling fluid added with the drilling fluid 3T treating agent meets the international environmental protection requirement, has toxicity data LC50 of more than 1000000, and can be used in environmental protection sensitive areas.
6. The mud cake plugging strength can meet the requirement that the well completion cement paste returns to a well mouth or is designed to be high, no leakage occurs, and no leakage occurs when the high-temperature high-pressure plugging evaluation instrument with the pressure of 100MPa and the temperature of 250 ℃ is tested.
The technical scheme of the invention is further described in detail through the drawings and the embodiments.
Drawings
FIG. 1 is a fluid loss profile comparison of a well slurry and a well slurry incorporating a drilling fluid 3T treatment agent;
FIG. 2 is a graph comparing performance of a base stock, a base stock with 2% drilling fluid 3T treatment added, and a base stock with 2% FLC2000 added against AV, API, HTHP;
FIG. 3 is a graph comparing performance of base stock, base stock with drilling fluid 3T treatment agent added, base stock needle with FLC2000 added, and base stock with domestic sample # 1 against bearing strength;
FIG. 4 is a plot of the microstructure of a mudcake with 1% FLC2000 and 1% drilling fluid 3T treatment agent added to the base slurry.
Detailed Description
Embodiments of the present invention will be further described with reference to the accompanying drawings.
As shown, a drilling fluid 3T treatment agent includes millimeter-sized cellulose, micron-sized cellulose, and nano-sized cellulose, wherein the millimeter-sized cellulose is divided into 1 millimeter-sized cellulose and 2 millimeter-sized cellulose, the 1 millimeter-sized cellulose accounts for 15%, the 2 millimeter-sized cellulose accounts for 30%, the micron-sized cellulose accounts for 20%, and the nano-sized cellulose accounts for 35%.
The using method of the drilling fluid 3T treating agent comprises the following steps:
step 1: grinding and screening cellulose to obtain 1 millimeter cellulose, 2 millimeter cellulose, micron-sized cellulose and nanometer-sized cellulose respectively;
step 2: for 1 mm cellulose, 2 mm cellulose, micron cellulose and nanoscale cellulose according to 3:6:4:7, proportioning by weight ratio to obtain a drilling fluid 3T treating agent;
step 3: the drilling fluid 3T treating agent is uniformly mixed with the drilling fluid and then used according to the conventional use method of the drilling fluid under the condition that the positive pressure difference is not higher than the fracture pressure of the stratum. When the drilling fluid 3T treating agent is used for leakage prevention and plugging of low, medium and high permeability stratum and microcrack stratum, stabilizing the well wall and improving the compressive strength of the stratum, the mixing ratio of the drilling fluid 3T treating agent and the drilling fluid is 0.3-3.0%. When the drilling fluid 3T treating agent is used for plugging small karst cave and large crack stratum, the treating agent is firstly matched with large particle bridging particles such as walnut shells and the like according to the requirement, then the treating agent and the drilling fluid are uniformly mixed according to the mass ratio of 3% -5% of the drilling fluid, and the treating agent and the drilling fluid are used according to the conventional use method of the drilling fluid.
Drilling fluid flow and fluid loss effect experiments
The base stock formulation in the table above is: from the table above, it can be seen that the 3T treatment agent of the drilling fluid has little effect on the rheological properties of the base slurry, and can reduce the API fluid loss and HTHP fluid loss of the base slurry, and the reduction of the fluid loss indicates that the quality of the mud cake can be improved and the permeability of the mud cake is reduced.
And taking site slurry, and performing an evaluation experiment in a pressure-bearing plugging instrument of 100MPa by using stratum sand of the pile 115-side flat 1 well as an experimental medium. 200g of sand with a particle size of (60-80) mesh was weighed into 400ml of well slurry stirred at high speed, and the volume of slurry filtrate at each fixed pressure difference for 10min was recorded, and the result is shown in FIG. 1. As can be seen from fig. 1, the drilling fluid added with the drilling fluid 3T treatment agent can effectively reduce fluid loss.
Sand bed filtration test
200g of sand which is cooled after being washed and dried by clear water and is 0.45-0.60 mm is added into a high-temperature high-pressure filtration instrument, the sand is paved after being soaked by water, 400ml of polymer drilling fluid is slowly added, the pressure is gradually increased to 3.5MPa, the filtration loss is respectively tested for 1min, 7.5min and 30min at normal temperature, and the depth of the filtrate entering a sand bed is measured. The experimental results are shown in the following table.
From the table, the polymer drilling fluid is completely lost through the sand bed, a small amount of the polymer drilling fluid is lost 1 minute before the drilling fluid 3T treating agent is added for experiments, and the polymer drilling fluid is not lost after 10 minutes, so that the polymer drilling fluid 3T treating agent enters the sand bed to form a blocking film rapidly, and the pores are effectively blocked. The thickness of the plugging film formed by the base slurry added with the drilling fluid 3T treating agent is less than 4mm. When the drilling fluid added with the drilling fluid 3T treating agent enters a sand bed, the drilling fluid is filtered through pores, and the plugging film is thin and tough under the action of pressure due to concentration, adsorption, water absorption expansion and filling of some active materials of the cationic polymer micelle, so that the fluid loss can be reduced along with the extension of time, and the stratum pressure resistance can be improved.
Compressive Strength experiment
And (3) pressurizing a high-temperature high-pressure slurry tank after the 30-min filtrate loss sand bed experiment is completed, and measuring the pressure when the plugging film is fractured and slurry is leaked. The core (permeability 200 millidarcy, porosity 22%) was used for the bearing capacity test, and the results are shown in the following table.
| Drilling fluid type | Sand bed pressure resistance, MPa | Rock core pressure resistance, MPa |
| Base slurry | 0 | 3.5 |
| Basal slurry +1%3T | 10.3 | 16.2 |
| Basal pulp +2%3T | 10.3 | 28.0 |
| Well slurry | 0 | 4.3 |
| Well slurry +1%3T | 10.3 | 18.0 |
The pressure resistance of the base slurry and the well slurry in the sand bed is zero, and the pressure resistance of the mud cake formed in the core is about 3-4 MPa. And (3) adding the drilling fluid with the 3T treating agent of 1% of the drilling fluid, and improving the bearing strength of the sand bed from 0 to more than 10MPa (nitrogen cylinder limit pressure). The 3T treating agent for the drilling fluid greatly improves the bearing capacity of the rock core to 28 megapascals. In field application, the leakage pressure and the burst pressure gradient can be improved, and the safety density window is enlarged.
Flow back experiment
In the table above, kg—nitrogen permeability; kw—standard brine permeability; ko-kerosene permeability; ko— kerosene permeability after drilling fluid contamination; k recovery-recovery rate of permeability of kerosene flowback. Drilling fluid pollution conditions: 3.0MPa/0.5h. As shown in the table, after 2% of drilling fluid 3T treating agent is added to two kinds of fractured rock samples with different permeabilities, the recovery rate of the permeability of the kerosene flowback is obviously improved and is more than 90%, and the flowback pressure difference is small.
Comparison experiment
The evaluation and comparison of the base slurry, the base slurry added with 2% of drilling fluid 3T treating agent and the base slurry added with 2% of FLC2000 are carried out aiming at AV, API and HTHP, the high temperature and high pressure filtration loss is measured at 120 ℃ and 3.5MPa, and the experimental result is shown in figure 2. As can be seen from fig. 2, the viscosity was better than FLC2000 for the drilling fluid 3T treatment; effects on water loss drilling fluid 3T treatments were comparable to FLC 2000.
The base slurry, the base slurry added with the drilling fluid 3T treating agent, the base slurry needle added with FLC2000 and the base slurry added with the domestic 1# sample are selected for evaluation and comparison of the pressure-bearing strength performance, and the experimental result is shown in figure 3. As can be seen from fig. 3, the pressure bearing strength of the sand bed is ordered: 3T > FLC2000> domestic 1# > base pulp.
As shown in fig. 4, which shows the microstructure of the mud cake with 1% flc2000 and 1% drilling fluid 3T treating agent added to the base slurry, as shown in fig. 4, the mud cake with the drilling fluid 3T treating agent added is more compact.
The average well diameter expansion ratio of the drilling fluid 3T treatment agent used for the 8-inclined 46 well is compared with that shown in the following table:
the first well has a diameter of 444.5mm, the second well has a diameter of 241.3mm, a 3T treatment agent for drilling fluid is used from 1310 m, the addition amount is 1%, the total amount is 1.25T, the drilling fluid is stable, the whole well has no block, the well wall is stable, and the average well diameter expansion rate is 0. Therefore, the drilling fluid 3T treating agent can effectively reduce the well diameter expansion rate.
After the block 76 is formed by using the drilling fluid 3T technology, the sleeve structure of the block is simplified, the surface sleeve is reduced to 150m from 350m, the technical sleeve is reduced to 1700m from about 2600m, the sleeve is saved by 70-80T for a single well, the sleeve cost is reduced by about 60 ten thousand yuan, the drilling period is saved, and the total cost is saved by more than 100 ten thousand yuan. Therefore, the drilling fluid 3T treating agent can effectively reduce the technical sleeve depth.
Therefore, the drilling fluid 3T treating agent with the structure and the use method thereof can form a compact and thin blocking layer on the well wall by utilizing the characteristic of the drilling fluid 3T treating agent, improve the bearing force of the well wall, reduce the permeability of the well wall and improve the drilling speed, the well cementation quality and the oil and gas well yield.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present invention and not for limiting it, and although the present invention has been described in detail with reference to the preferred embodiments, it will be understood by those skilled in the art that: the technical scheme of the invention can be modified or replaced by the same, and the modified technical scheme cannot deviate from the spirit and scope of the technical scheme of the invention.
Claims (4)
1. A drilling fluid 3T treatment agent, characterized in that: the cellulose comprises millimeter-sized cellulose, micron-sized cellulose and nanometer-sized cellulose, wherein the millimeter-sized cellulose is divided into 1 millimeter-sized cellulose and 2 millimeter-sized cellulose, the proportion of the 1 millimeter-sized cellulose is 15%, the proportion of the 2 millimeter-sized cellulose is 30%, the proportion of the micron-sized cellulose is 20%, and the proportion of the nanometer-sized cellulose is 35%.
2. The method of using the drilling fluid 3T treatment agent according to claim 1, wherein: the method comprises the following steps:
step 1: grinding and screening cellulose to obtain 1 millimeter cellulose, 2 millimeter cellulose, micron-sized cellulose and nanometer-sized cellulose respectively;
step 2: for 1 mm cellulose, 2 mm cellulose, micron cellulose and nanoscale cellulose according to 3:6:4:7, proportioning by weight ratio to obtain a drilling fluid 3T treating agent;
step 3: the drilling fluid 3T treating agent is uniformly mixed with the drilling fluid and then used according to the conventional use method of the drilling fluid under the condition that the positive pressure difference is not higher than the fracture pressure of the stratum.
3. The method of using a drilling fluid 3T treatment according to claim 2, wherein: when the drilling fluid 3T treating agent is used for leakage prevention and plugging of low, medium and high permeability stratum and microcrack stratum, stabilizing the well wall and improving the compressive strength of the stratum, the mixing ratio of the drilling fluid 3T treating agent and the drilling fluid is 0.3-3.0%.
4. A method of using the drilling fluid 3T treatment agent according to claim 3, wherein: when the drilling fluid 3T treating agent is used for plugging small karst cave and large crack stratum, the treating agent is firstly matched with large particle bridging particles such as walnut shells and the like according to the requirement, then the treating agent and the drilling fluid are uniformly mixed according to the mass ratio of 3% -5% of the drilling fluid, and the treating agent and the drilling fluid are used according to the conventional use method of the drilling fluid.
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