CN116836689A - Water-based drilling fluid base slurry additive and water-based drilling fluid - Google Patents
Water-based drilling fluid base slurry additive and water-based drilling fluid Download PDFInfo
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- 238000005553 drilling Methods 0.000 title claims abstract description 137
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 134
- 229910001868 water Inorganic materials 0.000 title claims abstract description 129
- 239000012530 fluid Substances 0.000 title claims abstract description 123
- 239000002002 slurry Substances 0.000 title claims abstract description 51
- 239000000654 additive Substances 0.000 title claims abstract description 39
- 230000000996 additive effect Effects 0.000 title claims abstract description 35
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 45
- 229920002472 Starch Polymers 0.000 claims abstract description 44
- 239000008107 starch Substances 0.000 claims abstract description 42
- 235000019698 starch Nutrition 0.000 claims abstract description 41
- 239000000706 filtrate Substances 0.000 claims abstract description 40
- 239000000178 monomer Substances 0.000 claims abstract description 39
- 125000000391 vinyl group Chemical group [H]C([*])=C([H])[H] 0.000 claims abstract description 39
- 229920002554 vinyl polymer Polymers 0.000 claims abstract description 39
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 38
- 239000011248 coating agent Substances 0.000 claims abstract description 38
- 229920000642 polymer Polymers 0.000 claims abstract description 38
- 239000003223 protective agent Substances 0.000 claims abstract description 36
- 239000010687 lubricating oil Substances 0.000 claims abstract description 32
- 239000004005 microsphere Substances 0.000 claims abstract description 28
- 239000002121 nanofiber Substances 0.000 claims abstract description 10
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 33
- 239000003921 oil Substances 0.000 claims description 31
- 229910000278 bentonite Inorganic materials 0.000 claims description 18
- 239000000440 bentonite Substances 0.000 claims description 18
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims description 18
- 239000000835 fiber Substances 0.000 claims description 18
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 16
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 claims description 13
- 239000010428 baryte Substances 0.000 claims description 13
- 229910052601 baryte Inorganic materials 0.000 claims description 13
- 238000009826 distribution Methods 0.000 claims description 5
- 239000002245 particle Substances 0.000 claims description 5
- 230000000694 effects Effects 0.000 abstract description 8
- 230000009467 reduction Effects 0.000 abstract description 3
- 230000000052 comparative effect Effects 0.000 description 15
- 239000007788 liquid Substances 0.000 description 13
- 238000002156 mixing Methods 0.000 description 13
- 238000003756 stirring Methods 0.000 description 13
- 239000013078 crystal Substances 0.000 description 12
- 238000000034 method Methods 0.000 description 11
- 238000002360 preparation method Methods 0.000 description 10
- 238000007789 sealing Methods 0.000 description 9
- 239000000243 solution Substances 0.000 description 8
- 238000001723 curing Methods 0.000 description 7
- 230000008569 process Effects 0.000 description 7
- 238000009835 boiling Methods 0.000 description 6
- 238000001035 drying Methods 0.000 description 6
- 230000005484 gravity Effects 0.000 description 6
- 230000035699 permeability Effects 0.000 description 6
- 230000001603 reducing effect Effects 0.000 description 6
- 238000005406 washing Methods 0.000 description 6
- 239000004215 Carbon black (E152) Substances 0.000 description 5
- 241000209140 Triticum Species 0.000 description 5
- 235000021307 Triticum Nutrition 0.000 description 5
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- UGTZMIPZNRIWHX-UHFFFAOYSA-K sodium trimetaphosphate Chemical compound [Na+].[Na+].[Na+].[O-]P1(=O)OP([O-])(=O)OP([O-])(=O)O1 UGTZMIPZNRIWHX-UHFFFAOYSA-K 0.000 description 5
- 239000003381 stabilizer Substances 0.000 description 5
- 239000010902 straw Substances 0.000 description 5
- 238000012360 testing method Methods 0.000 description 5
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical group CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 4
- 239000002202 Polyethylene glycol Substances 0.000 description 4
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical group [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 4
- 238000001914 filtration Methods 0.000 description 4
- 238000010438 heat treatment Methods 0.000 description 4
- 229910017053 inorganic salt Inorganic materials 0.000 description 4
- 238000012423 maintenance Methods 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 229920001223 polyethylene glycol Polymers 0.000 description 4
- 238000011084 recovery Methods 0.000 description 4
- 239000000126 substance Substances 0.000 description 4
- 239000003431 cross linking reagent Substances 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 239000012153 distilled water Substances 0.000 description 3
- 229940057847 polyethylene glycol 600 Drugs 0.000 description 3
- 239000002904 solvent Substances 0.000 description 3
- 241000196324 Embryophyta Species 0.000 description 2
- SXRSQZLOMIGNAQ-UHFFFAOYSA-N Glutaraldehyde Chemical group O=CCCCC=O SXRSQZLOMIGNAQ-UHFFFAOYSA-N 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 229910000281 calcium bentonite Inorganic materials 0.000 description 2
- 235000013339 cereals Nutrition 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 238000001816 cooling Methods 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 239000008367 deionised water Substances 0.000 description 2
- 229910021641 deionized water Inorganic materials 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 230000001965 increasing effect Effects 0.000 description 2
- 230000009545 invasion Effects 0.000 description 2
- 150000002500 ions Chemical class 0.000 description 2
- IZWSFJTYBVKZNK-UHFFFAOYSA-N lauryl sulfobetaine Chemical group CCCCCCCCCCCC[N+](C)(C)CCCS([O-])(=O)=O IZWSFJTYBVKZNK-UHFFFAOYSA-N 0.000 description 2
- 239000012528 membrane Substances 0.000 description 2
- 239000011259 mixed solution Substances 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 239000001103 potassium chloride Substances 0.000 description 2
- 235000011164 potassium chloride Nutrition 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 239000012266 salt solution Substances 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 238000005303 weighing Methods 0.000 description 2
- 229940100445 wheat starch Drugs 0.000 description 2
- 239000002888 zwitterionic surfactant Substances 0.000 description 2
- 102000004190 Enzymes Human genes 0.000 description 1
- 108090000790 Enzymes Proteins 0.000 description 1
- 244000208060 Lawsonia inermis Species 0.000 description 1
- 238000005299 abrasion Methods 0.000 description 1
- 239000002280 amphoteric surfactant Substances 0.000 description 1
- 238000010420 art technique Methods 0.000 description 1
- 230000003796 beauty Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 230000000295 complement effect Effects 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000011109 contamination Methods 0.000 description 1
- 230000006837 decompression Effects 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 230000000887 hydrating effect Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 230000005764 inhibitory process Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 238000011056 performance test Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- XAEFZNCEHLXOMS-UHFFFAOYSA-M potassium benzoate Chemical compound [K+].[O-]C(=O)C1=CC=CC=C1 XAEFZNCEHLXOMS-UHFFFAOYSA-M 0.000 description 1
- 238000004321 preservation Methods 0.000 description 1
- 238000004537 pulping Methods 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 238000002791 soaking Methods 0.000 description 1
- 239000002689 soil Substances 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 239000004094 surface-active agent Substances 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
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/14—Clay-containing compositions
- C09K8/18—Clay-containing compositions characterised by the organic compounds
-
- 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
- C09K2208/12—Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating
-
- 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
- C09K2208/34—Lubricant additives
Landscapes
- 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)
- Dispersion Chemistry (AREA)
- Lubricants (AREA)
Abstract
The invention relates to a water-based drilling fluid base slurry additive and a water-based drilling fluid, and belongs to the technical field of drilling fluids. The water-based drilling fluid base slurry additive mainly comprises vinyl monomer multipolymer, a zwitterionic polymer coating agent, a filtrate reducer, an anti-collapse agent, a liquid lubricant and an oil-gas layer protective agent; the mass ratio of the vinyl monomer multipolymer to the zwitterionic polymer coating agent to the filtrate reducer to the anti-collapse agent to the liquid lubricant to the oil-gas layer protective agent is 0.2-0.4:0.3-0.5:0.5-1:1-2:4-8:2-3; the oil-gas layer protecting agent is nano-scale crosslinked starch microsphere and nano-scale fiber, and the mass ratio of the nano-scale crosslinked starch microsphere to the nano-scale fiber is 2-4:1. The water-based drilling fluid adopting the slurry additive has good compatibility and rheological property, obvious filtrate reduction failure effect, strong pressure-bearing plugging filtrate reduction capability and low damage to a reservoir.
Description
Technical Field
The invention relates to a water-based drilling fluid base slurry additive and a water-based drilling fluid, and belongs to the technical field of drilling fluids.
Background
The drilling fluid is the liquid used in the whole process from the drilling of an oil layer to the production of an oil well, has the functions of stabilizing the well wall, preventing the well kick caused by the invasion of the fluid into the well, cleaning drill cuttings and suspended matters carried at the bottom of the well, and the like, and is an important component part of oilfield chemicals. Along with the gradual development of well drilling to deep and complex, the requirements on the liquid of the well drilling are higher and higher, and the protection of hydrocarbon reservoirs is also more and more emphasized, so that in order to realize sustainable development, a well drilling liquid system which can effectively protect hydrocarbon reservoirs and has good comprehensive performance needs to be applied. As in the prior art, the chinese application of application publication No. CN102352224a discloses a salt-resistant, strong-inhibition, reservoir-protecting drilling fluid, which comprises the following components in parts by weight: 2 to 4 parts of bentonite, 1 to 3 parts of salt resistant soil, 0.1 to 0.2 part of calcined soda, 100 parts of water, 0.4 to 0.8 part of viscosity increasing agent ST-MH, 2 to 3 parts of filtrate reducing agent KNT, 0.2 to 0.6 part of shale inhibitor SET-H, 2 to 6 parts of organic composite potassium salt BPC, 2 to 3 parts of bridging agent MF-II and 2 to 3 parts of biological enzyme storage and preservation agent CVS. The drilling fluid prevents well wall collapse by improving the system inhibition and plugging property, controls underground complex conditions in the drilling process, however, certain defects still exist in the aspect of damage to a drilling reservoir in the use process of the drilling fluid, serious leakage is caused in a long-open hole horizontal section, serious reservoir damage is caused, and the drilling fluid cannot be recovered through post-treatment, so that gas production is low and development effect is low.
Disclosure of Invention
The invention aims to provide a water-based drilling fluid base slurry additive which can reduce damage of water-based drilling fluid to a reservoir.
The invention also aims to provide the water-based drilling fluid.
In order to achieve the above purpose, the water-based drilling fluid base slurry additive of the invention adopts the following technical scheme:
a water-based drilling fluid base slurry additive mainly comprises vinyl monomer multipolymer, amphoteric ion polymer coating agent, filtrate reducer, anti-collapse agent, liquid lubricant and oil-gas layer protecting agent; the mass ratio of the vinyl monomer multipolymer to the zwitterionic polymer coating agent to the filtrate reducer to the anti-collapse agent to the liquid lubricant to the oil-gas layer protecting agent is 0.2-0.4:0.3-0.5:0.5-1:1-2:4-8:2-3; the oil-gas layer protecting agent is nano-scale crosslinked starch microsphere and nano-scale fiber, and the mass ratio of the nano-scale crosslinked starch microsphere to the nano-scale fiber is 2-4:1.
When the water-based drilling fluid base slurry additive is used for water-based drilling fluid, the water-based drilling fluid has good compatibility and rheological property, obvious filtration-reducing and failure effect, strong pressure-bearing plugging filtration-reducing and failure capability and low damage to a reservoir.
The oil-gas layer protective agent in the water-based additive can play an important role in pressure bearing, temporary plugging and fluid loss reduction in the drilling process, and protect the reservoir from being damaged by drilling fluid, so that the reservoir has a higher permeability recovery value after plugging removal. The surface morphology of the fiber in the oil layer protective agent is in a bundle rod structure, the grain diameter is nano-scale, the starch microsphere is complementary in morphology and grain diameter, the nano-scale starch microsphere and the fiber with the diameter being nano-scale are compounded, and after bridging and plugging of the starch microsphere, micro-pores between the microsphere and stratum and between the microsphere and microsphere can be filled and plugged, so that a better filtration reducing effect is achieved.
Further, the mass ratio of the nanoscale crosslinked starch microsphere to the fiber is 3:1.
Further, the length of the fiber is 3-5 μm and the diameter is 80-100 nm. The fibers are plant fibers, such as wheat straw fibers. Further, the nanoscale crosslinked starch microspheres have the following particle size distribution characteristics: 200. d10 is more than or equal to 60nm, D50 is more than or equal to 400nm is more than or equal to 200nm, and D90 is more than or equal to 600 nm.
The nanoscale crosslinked starch microspheres may be prepared using prior art techniques, for example, by a process comprising the steps of: heating a solution obtained by mixing the esterified nano starch crystals with water to boiling, and keeping for a period of time; then adding amphoteric ion surfactant and stabilizer, mixing uniformly, adding inorganic salt solution and cross-linking agent, and making solid-liquid separation, washing and drying after reaction. The temperature of the solution obtained by mixing the esterified nano-starch crystals with water is raised to boiling and then the temperature is kept for 10 to 20 minutes, for example 15 minutes. The mass ratio of the esterified nano starch crystal, the stabilizer, the zwitterionic surfactant, the cross-linking agent and the inorganic salt is 2-4:25-35:1:0.4-0.6:0.6-0.9, for example, 2:30:1:0.5:0.75. The mass ratio of the esterified nano starch crystal to the water is 1-2:50, for example, 1:50. The temperature of the material is reduced to 10 to 30 c, for example 20 c, before the addition of the zwitterionic surfactant and the stabiliser. The stabilizer is polyethylene glycol, preferably a combination of polyethylene glycol 600 and polyethylene glycol 20000, and the mass ratio of the polyethylene glycol 600 to the polyethylene glycol 20000 is 4-6:1, for example, 5:1. The cross-linking agent is preferably glutaraldehyde. The amphoteric surfactant is dimethyl dodecyl sulfopropyl ammonium salt. The inorganic salt is potassium chloride solution with a concentration of 4-6%, for example 5%.
The esterified nano starch crystals are obtained by adding nano starch crystals into sodium trimetaphosphate solution, uniformly mixing, standing, heating, curing, solid-liquid separation, washing and drying. The mass ratio of the nano starch crystal to the sodium trimetaphosphate is 2.2:2.4-2.6, for example, 2.2:2.5. The concentration of the sodium trimetaphosphate solution is 4-6%, for example 5%. The time for the standing treatment after the uniform mixing is 0.5 to 1.5 hours, for example, 1 hour. The curing treatment is carried out at a temperature of 20-30 ℃, for example 25 ℃, for a time of 0.5-1.5 hours, for example 1 hour.
The nano starch crystal is obtained by heating a starch and water mixed solution to boiling, maintaining for a period of time, cooling, adding a poor solvent, standing, separating solid from liquid, washing and drying the obtained solid. The starch is preferably wheat starch. The mass ratio of the starch to the water is 4-6:100, for example 5:100. The temperature of the starch and water mixed solution is raised to boiling and then the temperature is kept for 15 to 25 minutes, for example, 20 minutes. The temperature is lowered after a period of time by lowering the temperature to 10-50 c, for example to 20 c. The poor solvent is preferably ethanol. The ratio of the addition amount of the poor solvent to the mass of the starch is 200:4 to 6, for example, 200:5.
The liquid lubricant can effectively reduce friction resistance between the drilling tool and the open hole well wall and between the drilling tool and the metal sleeve, and has the purposes of improving drilling speed, preventing drilling sticking and reducing abrasion of the drilling tool. Further, the liquid lubricant is white oil.
Further, the vinyl monomer multipolymer is a vinyl monomer multipolymer PAC141.
Further, the zwitterionic polymer coating agent is a zwitterionic polymer strong coating agent FA367. The strong coating agent FA367 of the zwitterionic polymer can inhibit the viscosity of drilling fluid, coat drill cuttings, stabilize the well wall, reduce the filtration loss and play a role in preventing collapse; meanwhile, the zwitterionic polymer strong coating agent can be uniformly mixed into the water-based drilling fluid through stirring, so that the uniformity of the water-based drilling fluid is ensured, and the chemical property is stable.
Further, the filtrate reducer is a high temperature resistant filtrate reducer. Still further, the fluid loss additive is a high temperature resistant fluid loss additive MG-1. The high-temperature-resistant filtrate reducer MG-1 can prevent clay from being dehydrated under high temperature conditions, enhance the gel protecting capability, and maintain the stability of drilling fluid gel by keeping and enhancing the water binding capability of the clay surface.
Further, the collapse preventing agent is non-fluorescent collapse preventing agent WFT-666 and/or collapse preventing agent FT-3000.
Further, the mass ratio of the vinyl monomer multipolymer to the zwitterionic polymer coating agent to the filtrate reducer to the anti-collapse agent to the liquid lubricant to the oil-gas layer protective agent is 0.2-0.4:0.4:0.6-1:1-2:4-7:2-3.
The technical scheme adopted by the water-based drilling fluid is as follows:
a water-based drilling fluid mainly comprises water-based base slurry and water-based drilling fluid base slurry additives; the additive mainly comprises vinyl monomer multipolymer, zwitterionic polymer coating agent, filtrate reducer, anti-collapse agent, liquid lubricant and oil-gas layer protective agent; the mass ratio of the vinyl monomer multipolymer to the zwitterionic polymer coating agent to the filtrate reducer to the anti-collapse agent to the liquid lubricant to the oil-gas layer protecting agent is 0.2-0.4:0.3-0.5:0.5-1:1-2:4-8:2-3; the oil-gas layer protecting agent is nano-scale crosslinked starch microsphere and nano-scale fiber, and the mass ratio of the nano-scale crosslinked starch microsphere to the nano-scale fiber is 2-4:1.
The water-based drilling fluid disclosed by the invention is low-cost, environment-friendly and water-based drilling fluid, and has the advantages of good compatibility and rheological property, obvious effect of reducing filtration, strong pressure-bearing plugging and reducing filtration capacity and low damage to a reservoir. The low-cost green environment-friendly water-based drilling fluid disclosed by the invention has the advantages that the core permeability recovery rate is more than 80%, the bearing capacity after film formation is more than 10MPa, and the water loss reducing effect is obvious.
Further, the mass ratio of the micron-sized crosslinked starch microsphere to the fiber is 3:1. The oil-gas layer protective agent has low cost of raw materials, is environment-friendly and easy to degrade, reduces the pollution of a reservoir, and reduces the application cost of each side of the added drilling fluid by more than 30 percent compared with the drilling fluid added with the prior non-penetrating agent.
The diameter of the fiber is nano-scale. Further, the length of the fiber is 3-5 μm and the diameter is 80-100 nm. The fibers are plant fibers, such as wheat straw fibers. The nanoscale crosslinked starch microsphere has the following particle size distribution characteristics: 200. d10 is more than or equal to 60nm, D50 is more than or equal to 400nm is more than or equal to 200nm, and D90 is more than or equal to 600 nm.
The water-based base slurry can be prepared by referring to the prior art of the prior water-based drilling fluid, and further, the water-based base slurry consists of bentonite, sodium carbonate and water; the mass ratio of bentonite to sodium carbonate to water is 3-5:0.5-1:100, for example 3-4:0.6-1:100. Among them, the bentonite is preferably calcium bentonite. Sodium carbonate can increase the rate of drilling fluids and adjust the pH of aqueous slurries. To optimize the pulping effect of the water-based pulp, further, the water-based pulp is prepared by a method comprising the steps of: mixing water, bentonite and sodium carbonate uniformly, and sealing and hydrating for 16-24 h.
Further, the mass of the vinyl monomer multipolymer in the additive to be used is 0.175 to 0.4g, for example, 0.175 to 0.35g, per 100mL of the aqueous slurry. The consumption of the vinyl monomer multipolymer in the drilling fluid is less, and the balance of various performances of the drilling fluid is realized on the basis of ensuring the operation economy.
Further, the water-based drilling fluid may include barite according to different formation conditions. Further, the density of the water-based drilling fluid is 1.25-1.29 g/cm 3 . When the water-based drilling fluid comprises barite, the preparation method of the water-based drilling fluid further comprises the following steps of: adding the water-based drilling fluid base slurry additive into the water-based base slurry, uniformly stirring, and sealing and curing. The method has simple process, can be carried out on the existing production equipment, and has good adaptability to field application.
Further, the liquid lubricant is white oil.
Further, the vinyl monomer multipolymer is a vinyl monomer multipolymer PAC141; the zwitterionic polymer coating agent is a zwitterionic polymer strong coating agent FA367; the filtrate reducer is a high temperature resistant filtrate reducer MG-1; the collapse preventing agent is non-fluorescent collapse preventing agent WFT-666 and/or collapse preventing agent FT-3000.
Further, the mass ratio of the vinyl monomer multipolymer to the zwitterionic polymer coating agent to the filtrate reducer to the anti-collapse agent to the liquid lubricant to the oil-gas layer protective agent is 0.2-0.4:0.4:0.6-1:1-2:4-7:2-3.
In order to optimize the uniformity of the water-based drilling fluid, further, the sealing maintenance time is 16-24 hours.
Detailed Description
The technical scheme of the invention is further described below in connection with the specific embodiments.
In the following examples, the zwitterionic polymer strong coating agent FA367, the high temperature resistant filtrate reducer MG-1, and the non-fluorescent collapse preventing agent WFT-666 were purchased from Henan golden horse Petroleum technology Co., ltd; vinyl monomer multipolymer PAC141 is purchased from Puyang beauty chemicals Co., ltd; liquid lubricant white oil was purchased from zheng flying chemical industry limited; industrial sodium carbonate was purchased from henna, yi Heng environmental protection technology Co., ltd; barite is available from southward Utility Co., nanyang. The bentonite used in the water-based slurry is first-order bentonite (calcium bentonite). The oil-gas layer protective agent is a mixture obtained by mixing nanoscale crosslinked starch microspheres and wheat straw fibers according to the mass ratio of 3:1, wherein the length of the wheat straw fibers is 3-5 mu m, and the diameter of the wheat straw fibers is 80-100 nm. The nano-scale crosslinked starch microsphere is prepared by referring to the method disclosed in Chinese patent publication No. CN 113122211B, and the specific preparation method comprises the following steps: adding 5 parts of wheat starch into 100 parts of deionized water, boiling for 20min, cooling the feed liquid to 20 ℃, dropwise adding 200 parts of ethanol into the feed liquid, standing after the dropwise addition to obtain a bottom insoluble substance, centrifuging, stirring and washing, and drying at 25 ℃ for 2.5h to obtain nano starch crystals; weighing 2.5 parts of sodium trimetaphosphate to prepare 50 parts of sodium trimetaphosphate solution, adding 2.2 parts of nano starch crystals, uniformly mixing, standing and soaking for 1h, curing the solution at 25 ℃ for 1h, centrifuging, stirring and washing, and drying at 25 ℃ for 2h to obtain esterified nano starch crystals; mixing 2 parts of esterified nano starch crystal with 100 parts of deionized water, heating the obtained solution to boiling, keeping the temperature for 15min, reducing the temperature of the feed liquid to 20 ℃, adding 30 parts of stabilizer (polyethylene glycol 600: polyethylene glycol 20000=5:1) and 1 part of dimethyl dodecyl sulfopropyl ammonium salt into the feed liquid, and fully and uniformly mixing; weighing 0.75 part of potassium chloride at 30 ℃ to prepare 15 parts of inorganic salt solution, simultaneously dripping 0.5 part of glutaraldehyde into the feed liquid at the same temperature, continuously reacting for 3 hours after the dripping is finished, and centrifuging, washing and drying to obtain white powdery nanoscale crosslinked starch microspheres; the prepared nanoscale crosslinked starch microsphere has the following typical particle size distribution characteristics: 200. d10 is more than or equal to 60nm, D50 is more than or equal to 400nm is more than or equal to 200nm, and D90 is more than or equal to 600 nm.
Example 1
The water-based drilling fluid base slurry additive of the embodiment consists of vinyl monomer multipolymer PAC141, a zwitterionic polymer strong coating agent FA367, a high-temperature-resistant filtrate reducer MG-1, a non-fluorescent collapse-preventing agent WFT666, liquid lubricant white oil and an oil and gas reservoir protecting agent; the mass ratio of the vinyl monomer multipolymer PAC141, the zwitterionic polymer strong coating agent FA367, the high temperature-resistant filtrate reducer MG-1, the collapse-preventing agent WFT666, the liquid lubricant white oil and the oil and gas layer protective agent is 0.7:1.4:3.5:3.5:14:7.
Example 2
The water-based drilling fluid base slurry additive of the embodiment consists of vinyl monomer multipolymer PAC141, a zwitterionic polymer strong coating agent FA367, a high-temperature-resistant filtrate reducer MG-1, a non-fluorescent collapse-preventing agent WFT666, liquid lubricant white oil and an oil and gas reservoir protecting agent; the mass ratio of the vinyl monomer multipolymer PAC141, the zwitterionic polymer strong coating agent FA367, the high temperature resistant filtrate reducer MG-1, the non-fluorescent anti-collapse agent WFT666, the liquid lubricant white oil and the oil and gas layer protective agent is 1.4:1.4:2.1:7:24:7.
Example 3
The water-based drilling fluid base slurry additive of the embodiment consists of vinyl monomer multipolymer PAC141, a zwitterionic polymer strong coating agent FA367, a high-temperature-resistant filtrate reducer MG-1, a non-fluorescent collapse-preventing agent WFT666, liquid lubricant white oil and an oil and gas reservoir protecting agent; the mass ratio of the vinyl monomer multipolymer PAC141, the zwitterionic polymer strong coating agent FA367, the high temperature-resistant filtrate reducer MG-1, the collapse-preventing agent WFT666, the liquid lubricant white oil and the oil and gas layer protective agent is 1.4:1.4:2.8:3.5:21:10.5.
Example 4
The water-based drilling fluid of the embodiment is a low-cost green environment-friendly water-based drilling fluid, and consists of water-based slurry, barite and additives; wherein the water-based slurry is obtained by mixing water, bentonite and industrial sodium carbonate, and the mass ratio of the water to the bentonite to the industrial sodium carbonate is 350:14:2.1; the additive consists of vinyl monomer multipolymer PAC141, a zwitterionic polymer strong coating agent FA367, a high temperature resistant filtrate reducer MG-1, a non-fluorescent anti-collapse agent WFT666, a liquid lubricant white oil and an oil-gas layer protective agent, wherein the mass ratio of the vinyl monomer multipolymer PAC141, the zwitterionic polymer strong coating agent FA367, the high temperature resistant filtrate reducer MG-1, the non-fluorescent anti-collapse agent WFT666, the liquid lubricant white oil and the oil-gas layer protective agent is 0.7:1.4:3.5:3.5:14:7.
The preparation method of the water-based drilling fluid comprises the following steps:
1) Preparation of aqueous slurry: bentonite and industrial sodium carbonate are added into distilled water, stirred at high speed for 20 minutes, filled into a closed wide-mouth bottle, and hydrated for 24 hours at room temperature to obtain water-based slurry.
2) Adding an additive into the water-based base slurry under the stirring condition, stirring at a high speed for 30min, and sealing and curing for 24h; the usage amount of each component in each 400mL of water-based slurry corresponding additive is as follows: vinyl monomer multipolymer PAC 141.7 g, zwitterionic polymer strong coating agent FA 367.4 g, high temperature resistant filtrate reducer MG-1.5 g, non-fluorescent anti-collapse agent WFT 666.5 g, liquid lubricant white oil 14g and oil and gas reservoir protective agent 7g; after sealing maintenance, the specific gravity of drilling fluid is 1.25-1.29 g/cm 3 And adding barite, and stirring at a high speed for 10min to obtain the water-based drilling fluid.
Example 5
The water-based drilling fluid of the embodiment is a low-cost green environment-friendly water-based drilling fluid, and consists of water-based slurry, barite and additives; wherein the water-based slurry is obtained by mixing water, bentonite and industrial sodium carbonate, and the mass ratio of the water to the bentonite to the industrial sodium carbonate is 350:10.5:3.5; the additive consists of vinyl monomer multipolymer PAC141, a zwitterionic polymer strong coating agent FA367, a high temperature resistant filtrate reducer MG-1, a non-fluorescent anti-collapse agent WFT666, a liquid lubricant white oil and an oil-gas layer protective agent, wherein the mass ratio of the vinyl monomer multipolymer PAC141, the zwitterionic polymer strong coating agent FA367, the high temperature resistant filtrate reducer MG-1, the non-fluorescent anti-collapse agent WFT666, the liquid lubricant white oil and the oil-gas layer protective agent is 1.4:1.4:2.1:7:24:7.
The preparation method of the water-based drilling fluid comprises the following steps:
1) Preparation of aqueous slurry: bentonite and industrial sodium carbonate are added into distilled water, stirred at high speed for 20 minutes, filled into a closed wide-mouth bottle, and hydrated for 24 hours at room temperature to obtain water-based slurry.
2) Adding an additive into the water-based base slurry under the stirring condition, stirring at a high speed for 30min, and sealing and curing for 24h; the usage amount of each component in each 400mL of water-based slurry corresponding additive is as follows: vinyl monomer multipolymer PAC 141.4 g, zwitterionic polymer strong coating agent FA367 1.4g, high temperature resistant filtrate reducer MG-1.1 g, non-fluorescent anti-collapse agent WFT666 7g, liquid lubricant white oil24g of a hydrocarbon reservoir protective agent 7g; after sealing maintenance, the specific gravity of drilling fluid is 1.26g/cm 3 And adding barite, and stirring at a high speed for 10min to obtain the water-based drilling fluid.
Example 6
The water-based drilling fluid of the embodiment is a low-cost green environment-friendly water-based drilling fluid, and consists of water-based slurry, barite, additives and; wherein the water-based slurry is obtained by mixing water, bentonite and industrial sodium carbonate, and the mass ratio of the water to the bentonite to the industrial sodium carbonate is 350:14:2.8; the additive consists of vinyl monomer multipolymer PAC141, a zwitterionic polymer strong coating agent FA367, a high temperature resistant filtrate loss reducer MG-1, a non-fluorescent anti-collapse agent WFT666, a liquid lubricant white oil and an oil-gas layer protective agent; the mass ratio of the vinyl monomer multipolymer PAC141, the zwitterionic polymer strong coating agent FA367, the high temperature resistant filtrate reducer MG-1, the non-fluorescent anti-collapse agent WFT666, the liquid lubricant white oil and the oil and gas layer protective agent is 1.4:1.4:2.8:3.5:21:10.5.
The preparation method of the water-based drilling fluid comprises the following steps:
1) Preparation of aqueous slurry: bentonite and industrial sodium carbonate are added into distilled water, stirred at high speed for 20 minutes, filled into a closed wide-mouth bottle, and hydrated for 24 hours at room temperature to obtain water-based slurry.
2) Adding an additive into the water-based base slurry under the stirring condition, stirring at a high speed for 30min, and sealing and curing for 24h; the usage amount of each component in each 400mL of water-based slurry corresponding additive is as follows: vinyl monomer multipolymer PAC 141.4 g, zwitterionic polymer strong coating agent FA367 1.4g, high temperature resistant filtrate reducer MG-1.8 g, non-fluorescent anti-collapse agent WFT 666.5 g, liquid lubricant white oil 21g and oil and gas reservoir protective agent 10.5g; after sealing maintenance, the specific gravity of drilling fluid is 1.26g/cm 3 And adding barite, and stirring at a high speed for 10min to obtain the water-based drilling fluid.
Comparative example 1
The drilling fluid of this comparative example differs from the water-based drilling fluid of example 4 only in that: the comparative example does not add a hydrocarbon reservoir protectant. This comparative example the addition of barite to a water-based drilling fluid at the time of preparation resulted in a specific gravity of 1.26g/cm for the water-based drilling fluid 3 。
Comparative example 2
The drilling fluid of this comparative example differs from the water-based drilling fluid of example 4 only in that: this comparative example replaces the hydrocarbon reservoir protectant in the water-based drilling fluid of example 4 with starch microspheres. This comparative example the addition of barite to a water-based drilling fluid at the time of preparation resulted in a specific gravity of 1.26g/cm for the water-based drilling fluid 3 。
Experimental example 1
Performance tests were performed on the drilling fluids of examples 4 to 6 and comparative example 1. (in table 1, green environmental protection type drilling fluids 1 to 4 are drilling fluids obtained by adding different amounts of barite in example 4, respectively. Blank groups are comparative example 1.) the experimental effects of the drilling fluids of other examples are equivalent to those of example 4. The pressure-bearing temporary plugging performance of the drilling fluid is evaluated by adopting unconventional reservoir evaluation equipment, and the specific steps are as follows: (1) Comparative example 1 (no oil blanket protectant) served as a blank. The drilling fluids of examples 4-6 were used as test groups; (2) test blank. The pump speed was 1.0mL/min, and the drilling fluid of comparative example 2 was displaced using a permeameter, and displacement was stopped when the tail end of the core holder was discharged. Recording the inlet-outlet pressure difference P at the moment 1 Decompression and pipeline evacuation; (3) test set. The pump speed was 1.0mL/min and the core was displaced with the different example drilling fluids. When the pressure reaches a stable value, recording the highest value P 2 Stopping pumping, releasing pressure and evacuating the pipeline; (4) calculating the membrane bearing capacity of the drilling fluid. The pressure value of the test group minus the pressure value of the blank group is equal to the pressure bearing strength of the membrane. I.e. bearing strength p=p 2 -P 1 . The results are shown in Table 1.
Table 1 film bearing strength of water-based drilling fluids (core permeability 120 x 10) -3 μm 2 )
| Experimental formulation | Specific gravity of drilling fluid/(g/cm) 3 ) | Maximum bearing value/MPa | Bearing strength/MPa |
| Environment-friendly water-based drilling fluid 1 | 1.25 | 12.07 | 8.52 |
| Environment-friendly water-based drilling fluid 2 | 1.26 | 13.96 | 10.41 |
| Green environment-friendly water-based drilling fluid 3 | 1.27 | 14.89 | 11.34 |
| Green environment-friendly water-based drilling fluid 4 | 1.28 | 15.30 | 11.75 |
| Example 5 | 1.26 | 11.86 | 8.31 |
| Example 6 | 1.26 | 11.74 | 8.19 |
| Blank group | 1.26 | 3.55 | - |
As can be seen from Table 1, the permeability was measured using a liquid at 120X 10 -3 μm 2 When the drilling fluid of the comparative example is discharged from the tail end of the core holder, the pressure difference between an inlet and an outlet is smaller, which indicates that the used drilling fluid does not form an effective blocking film in the core and only has weaker bearing capacity. In contrast, after the green environment-friendly water-based drilling fluid is added, the inlet pressure is continuously increased along with the increase of the pumping volume and then is stable, no liquid is discharged from the tail end of the core, and the fact that the drilling fluid forms a plugging film on the section of the core shows that the water-based drilling fluid has strong pressure-bearing temporary plugging capability.
Experimental example 2
Application effect of green environment-friendly drilling fluid 1 in experimental example 1 in 1319 well
The 1319 well is a production well positioned in a nose-shaped structural band of a Nanyang sunken store, belongs to a Nanyang sunken store oilfield south 38 broken block of a Nanyang basin, is a directional well, and is designed to be 3550m in depth and 3550m in depth. The low cost green water-based drilling fluid was used in this well and the in situ real drilling fluid performance is shown in table 2 below.
Table 2 low cost green water-based drilling fluid real drilling performance
| Well depth/m | D/(g/cm 3 ) | FV/s | FL/mL | AV/mPa.s | PV/mPa·s | YP/Pa | GEL/Pa | pH |
| 2115 | 1.25 | 57 | 4.2 | 32 | 22 | 10 | 3/6 | 8.5 |
| 2344 | 1.29 | 62 | 3.5 | 33 | 24 | 9 | 3/7 | 8 |
As can be seen from Table 2, the depth of drilling increases and the fluid loss of 1319 well slurry decreases from 4.2mL to 3.5mL. The test results of apparent viscosity and plastic viscosity of the well slurry show that the well slurry using the low-cost green environment-friendly water-based drilling fluid has no significant viscosity increase along with the increase of the drilling depth, which shows that the water-based drilling fluid is good.
To further evaluate the reservoir protection effect of the water-based drilling fluid, a core pollution experiment was performed by taking 1319 field well slurry and core, and the results are shown in table 3. According to SY/T6540-2002 'method for evaluating damage to oil layer by drilling fluid completion fluid indoors', a high-temperature high-pressure dynamic damage evaluation instrument is adopted to simulate reservoir invasion and damage determination under the actual stratum drilling and completion fluid circulation state.
Table 3 comparative core dynamic contamination experiments
As can be seen from table 3, the core is plugged by the water-based drilling fluid, and the recovery value of the core permeability after plugging removal is more than 82.07%; in contrast, after the comparative drilling fluid pollutes the rock core, the permeability recovery value of the unblocked rock core is generally low, which indicates that the green environment-friendly water-based drilling fluid can effectively reduce the damage to the reservoir stratum in the drilling process.
Claims (10)
1. A water-based drilling fluid base slurry additive, characterized in that: the anti-collapse agent mainly comprises vinyl monomer multipolymer, a zwitterionic polymer coating agent, a filtrate reducer, an anti-collapse agent, a liquid lubricant and an oil-gas layer protective agent; the mass ratio of the vinyl monomer multipolymer to the zwitterionic polymer coating agent to the filtrate reducer to the anti-collapse agent to the liquid lubricant to the oil-gas layer protecting agent is 0.2-0.4:0.3-0.5:0.5-1:1-2:4-8:2-3; the oil-gas layer protecting agent is nano-scale crosslinked starch microsphere and nano-scale fiber, and the mass ratio of the nano-scale crosslinked starch microsphere to the nano-scale fiber is 2-4:1.
2. The water-based drilling fluid base slurry additive of claim 1, wherein: the length of the fiber is 3-5 mu m, and the diameter is 80-100 nm; the nanoscale crosslinked starch microsphere has the following particle size distribution characteristics: 200. d10 is more than or equal to 60nm, D50 is more than or equal to 400nm is more than or equal to 200nm, and D90 is more than or equal to 600 nm.
3. The water-based drilling fluid base slurry additive according to claim 1 or 2, characterized in that: the vinyl monomer multipolymer is a vinyl monomer multipolymer PAC141; the zwitterionic polymer coating agent is a zwitterionic polymer strong coating agent FA367; the filtrate reducer is a high temperature resistant filtrate reducer MG-1; the collapse preventing agent is non-fluorescent collapse preventing agent WFT-666 and/or collapse preventing agent FT-3000.
4. A water-based drilling fluid, characterized in that: the water-based drilling fluid additive mainly comprises water-based base slurry and a water-based drilling fluid base slurry additive; the additive mainly comprises vinyl monomer multipolymer, zwitterionic polymer coating agent, filtrate reducer, anti-collapse agent, liquid lubricant and oil-gas layer protective agent; the mass ratio of the vinyl monomer multipolymer to the zwitterionic polymer coating agent to the filtrate reducer to the anti-collapse agent to the liquid lubricant to the oil-gas layer protecting agent is 0.2-0.4:0.3-0.5:0.5-1:1-2:4-8:2-3; the oil-gas layer protecting agent is nano-scale crosslinked starch microsphere and nano-scale fiber, and the mass ratio of the nano-scale crosslinked starch microsphere to the nano-scale fiber is 2-4:1.
5. The water-based drilling fluid of claim 4, wherein: the length of the fiber is 3-5 mu m, and the diameter is 80-100 nm; the nanoscale crosslinked starch microsphere has the following particle size distribution characteristics: 200. d10 is more than or equal to 60nm, D50 is more than or equal to 400nm is more than or equal to 200nm, and D90 is more than or equal to 600 nm.
6. The water-based drilling fluid according to claim 4 or 5, characterized in that: the water-based base slurry consists of bentonite, sodium carbonate and water; the mass ratio of bentonite to sodium carbonate to water is 3-5:0.5-1:100.
7. The water-based drilling fluid of claim 6, wherein: the mass of the vinyl monomer multipolymer PAC141 in the additive correspondingly adopted per 100mL of the water-based slurry is 0.175-0.4 g.
8. The water-based drilling fluid of claim 7, wherein: the water-based drilling fluid also comprises barite, and the density of the water-based drilling fluid is 1.25-1.29 g/cm 3 。
9. The water-based drilling fluid according to claim 4 or 5, characterized in that: the liquid lubricant is white oil.
10. The water-based drilling fluid according to claim 4 or 5, characterized in that: the vinyl monomer multipolymer is a vinyl monomer multipolymer PAC141; the zwitterionic polymer coating agent is a zwitterionic polymer strong coating agent FA367; the filtrate reducer is a high temperature resistant filtrate reducer MG-1; the collapse preventing agent is non-fluorescent collapse preventing agent WFT-666 and/or collapse preventing agent FT-3000.
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