CN117535037A - Shale gas green water-based drilling fluid and application thereof - Google Patents
Shale gas green water-based drilling fluid and application thereof Download PDFInfo
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- CN117535037A CN117535037A CN202311483942.5A CN202311483942A CN117535037A CN 117535037 A CN117535037 A CN 117535037A CN 202311483942 A CN202311483942 A CN 202311483942A CN 117535037 A CN117535037 A CN 117535037A
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- 238000005553 drilling Methods 0.000 title claims abstract description 102
- 239000012530 fluid Substances 0.000 title claims abstract description 93
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 92
- 230000005764 inhibitory process Effects 0.000 claims abstract description 47
- 239000003381 stabilizer Substances 0.000 claims abstract description 37
- 239000002981 blocking agent Substances 0.000 claims abstract description 27
- 239000000706 filtrate Substances 0.000 claims abstract description 24
- 239000000314 lubricant Substances 0.000 claims abstract description 22
- 239000000463 material Substances 0.000 claims abstract description 17
- 229910000278 bentonite Inorganic materials 0.000 claims abstract description 15
- 239000000440 bentonite Substances 0.000 claims abstract description 15
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims abstract description 15
- 239000000654 additive Substances 0.000 claims abstract description 10
- 230000000996 additive effect Effects 0.000 claims abstract description 10
- 229920002472 Starch Polymers 0.000 claims description 42
- 239000008107 starch Substances 0.000 claims description 42
- 235000019698 starch Nutrition 0.000 claims description 42
- 229920000881 Modified starch Polymers 0.000 claims description 26
- 239000004368 Modified starch Substances 0.000 claims description 26
- 235000019426 modified starch Nutrition 0.000 claims description 26
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 25
- 239000003638 chemical reducing agent Substances 0.000 claims description 22
- 238000006243 chemical reaction Methods 0.000 claims description 21
- 239000000047 product Substances 0.000 claims description 20
- 238000002156 mixing Methods 0.000 claims description 18
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 17
- 239000002202 Polyethylene glycol Substances 0.000 claims description 17
- 229920001223 polyethylene glycol Polymers 0.000 claims description 17
- 238000006266 etherification reaction Methods 0.000 claims description 16
- 125000002057 carboxymethyl group Chemical group [H]OC(=O)C([H])([H])[*] 0.000 claims description 14
- 239000001913 cellulose Substances 0.000 claims description 14
- 229920002678 cellulose Polymers 0.000 claims description 14
- 239000003795 chemical substances by application Substances 0.000 claims description 14
- 229910021389 graphene Inorganic materials 0.000 claims description 13
- 238000000034 method Methods 0.000 claims description 13
- ZLMJMSJWJFRBEC-UHFFFAOYSA-N Potassium Chemical compound [K] ZLMJMSJWJFRBEC-UHFFFAOYSA-N 0.000 claims description 12
- 229910052700 potassium Inorganic materials 0.000 claims description 12
- 239000011591 potassium Substances 0.000 claims description 12
- 238000004132 cross linking Methods 0.000 claims description 10
- BVBIQASDHXEFKW-UHFFFAOYSA-N P1(OCCCCO1)=O.C(CN)N.[Na] Chemical compound P1(OCCCCO1)=O.C(CN)N.[Na] BVBIQASDHXEFKW-UHFFFAOYSA-N 0.000 claims description 8
- IOOLLUXHARIZLZ-UHFFFAOYSA-N [Na].NC1CCOP(=O)O1 Chemical compound [Na].NC1CCOP(=O)O1 IOOLLUXHARIZLZ-UHFFFAOYSA-N 0.000 claims description 8
- -1 aminotrimethylene sodium phosphonate Chemical compound 0.000 claims description 8
- YPPQYORGOMWNMX-UHFFFAOYSA-L sodium phosphonate pentahydrate Chemical compound [Na+].[Na+].[O-]P([O-])=O YPPQYORGOMWNMX-UHFFFAOYSA-L 0.000 claims description 8
- PIICEJLVQHRZGT-UHFFFAOYSA-N Ethylenediamine Chemical compound NCCN PIICEJLVQHRZGT-UHFFFAOYSA-N 0.000 claims description 7
- 230000001105 regulatory effect Effects 0.000 claims description 7
- 125000000383 tetramethylene group Chemical group [H]C([H])([*:1])C([H])([H])C([H])([H])C([H])([H])[*:2] 0.000 claims description 7
- GOOHAUXETOMSMM-UHFFFAOYSA-N Propylene oxide Chemical compound CC1CO1 GOOHAUXETOMSMM-UHFFFAOYSA-N 0.000 claims description 6
- 239000006087 Silane Coupling Agent Substances 0.000 claims description 6
- 239000003921 oil Substances 0.000 claims description 5
- LTVDFSLWFKLJDQ-UHFFFAOYSA-N α-tocopherolquinone Chemical group CC(C)CCCC(C)CCCC(C)CCCC(C)(O)CCC1=C(C)C(=O)C(C)=C(C)C1=O LTVDFSLWFKLJDQ-UHFFFAOYSA-N 0.000 claims description 4
- 230000003113 alkalizing effect Effects 0.000 claims description 3
- 230000008569 process Effects 0.000 claims description 3
- 239000000377 silicon dioxide Substances 0.000 claims description 3
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 claims description 2
- 239000007789 gas Substances 0.000 abstract description 44
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 abstract description 16
- 239000003345 natural gas Substances 0.000 abstract description 8
- 239000003209 petroleum derivative Substances 0.000 abstract description 8
- 230000007613 environmental effect Effects 0.000 abstract description 6
- 230000001050 lubricating effect Effects 0.000 abstract description 5
- 230000009467 reduction Effects 0.000 abstract description 3
- 238000003756 stirring Methods 0.000 description 49
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 45
- 239000007795 chemical reaction product Substances 0.000 description 16
- 229940092782 bentonite Drugs 0.000 description 12
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 10
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 10
- 239000010428 baryte Substances 0.000 description 10
- 229910052601 baryte Inorganic materials 0.000 description 10
- 239000005543 nano-size silicon particle Substances 0.000 description 10
- 239000002245 particle Substances 0.000 description 10
- 238000002360 preparation method Methods 0.000 description 10
- 235000012239 silicon dioxide Nutrition 0.000 description 10
- ONCZQWJXONKSMM-UHFFFAOYSA-N dialuminum;disodium;oxygen(2-);silicon(4+);hydrate Chemical compound O.[O-2].[O-2].[O-2].[O-2].[O-2].[O-2].[O-2].[O-2].[O-2].[O-2].[O-2].[O-2].[Na+].[Na+].[Al+3].[Al+3].[Si+4].[Si+4].[Si+4].[Si+4] ONCZQWJXONKSMM-UHFFFAOYSA-N 0.000 description 9
- 229940080314 sodium bentonite Drugs 0.000 description 9
- 229910000280 sodium bentonite Inorganic materials 0.000 description 9
- 239000000230 xanthan gum Substances 0.000 description 9
- 229920001285 xanthan gum Polymers 0.000 description 9
- 235000010493 xanthan gum Nutrition 0.000 description 9
- 229940082509 xanthan gum Drugs 0.000 description 9
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical group [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 8
- 238000001035 drying Methods 0.000 description 8
- 238000000227 grinding Methods 0.000 description 7
- 229920002261 Corn starch Polymers 0.000 description 6
- 239000008120 corn starch Substances 0.000 description 6
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 5
- 239000003054 catalyst Substances 0.000 description 5
- 239000000203 mixture Substances 0.000 description 5
- 229910052757 nitrogen Inorganic materials 0.000 description 5
- 238000005096 rolling process Methods 0.000 description 5
- 238000012360 testing method Methods 0.000 description 5
- 235000015112 vegetable and seed oil Nutrition 0.000 description 5
- 239000008158 vegetable oil Substances 0.000 description 5
- 238000001816 cooling Methods 0.000 description 4
- 230000000694 effects Effects 0.000 description 4
- 238000010438 heat treatment Methods 0.000 description 4
- 235000019198 oils Nutrition 0.000 description 4
- 238000007873 sieving Methods 0.000 description 4
- 229910000029 sodium carbonate Inorganic materials 0.000 description 4
- 238000005303 weighing Methods 0.000 description 4
- 239000008186 active pharmaceutical agent Substances 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- XDLMVUHYZWKMMD-UHFFFAOYSA-N 3-trimethoxysilylpropyl 2-methylprop-2-enoate Chemical group CO[Si](OC)(OC)CCCOC(=O)C(C)=C XDLMVUHYZWKMMD-UHFFFAOYSA-N 0.000 description 2
- BPQQTUXANYXVAA-UHFFFAOYSA-N Orthosilicate Chemical compound [O-][Si]([O-])([O-])[O-] BPQQTUXANYXVAA-UHFFFAOYSA-N 0.000 description 2
- WFRXSOIFNFJAFL-UHFFFAOYSA-N P1(OCCCCO1)=O.C(CN)N Chemical compound P1(OCCCCO1)=O.C(CN)N WFRXSOIFNFJAFL-UHFFFAOYSA-N 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 229920003023 plastic Polymers 0.000 description 2
- 239000004033 plastic Substances 0.000 description 2
- 229920000768 polyamine Polymers 0.000 description 2
- CMQAMENQCKNUPB-UHFFFAOYSA-N NC1CCOP(=O)O1 Chemical compound NC1CCOP(=O)O1 CMQAMENQCKNUPB-UHFFFAOYSA-N 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000006978 adaptation Effects 0.000 description 1
- VXAUWWUXCIMFIM-UHFFFAOYSA-M aluminum;oxygen(2-);hydroxide Chemical compound [OH-].[O-2].[Al+3] VXAUWWUXCIMFIM-UHFFFAOYSA-M 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- 238000003556 assay Methods 0.000 description 1
- 230000001580 bacterial effect Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000009920 chelation Effects 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 230000036571 hydration Effects 0.000 description 1
- 238000006703 hydration reaction Methods 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 229910017053 inorganic salt Inorganic materials 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 231100000053 low toxicity Toxicity 0.000 description 1
- 239000010687 lubricating oil Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000002105 nanoparticle Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000004537 pulping Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 230000001629 suppression Effects 0.000 description 1
- 231100000419 toxicity Toxicity 0.000 description 1
- 230000001988 toxicity Effects 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/14—Clay-containing compositions
- C09K8/18—Clay-containing compositions characterised by the organic compounds
- C09K8/20—Natural organic compounds or derivatives thereof, e.g. polysaccharides or lignin derivatives
- C09K8/206—Derivatives of other natural products, e.g. cellulose, starch, sugars
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/14—Clay-containing compositions
- C09K8/18—Clay-containing compositions characterised by the organic compounds
- C09K8/22—Synthetic organic compounds
- C09K8/24—Polymers
-
- 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
- C09K2208/10—Nanoparticle-containing well treatment fluids
-
- 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
Landscapes
- Chemical & Material Sciences (AREA)
- Dispersion Chemistry (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Lubricants (AREA)
Abstract
The invention provides a shale gas green water-based drilling fluid and application thereof, and belongs to the field of petroleum and natural gas drilling. The shale gas green water-based drilling fluid disclosed by the invention comprises the following components: water, bentonite, viscosifier, alkalinity regulator, shale inhibition stabilizer, fluid loss additive, shale blocking agent, lubricant and weighting material. The shale gas green water-based drilling fluid has good rheological property, strong inhibition, good filtrate loss reduction performance, plugging performance and lubricating performance, can keep the stability of the shale stratum well wall for a long time, reduces the drilling friction resistance, has good biodegradability, and meets the environmental protection requirement.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas drilling, in particular to shale gas green water-based drilling fluid and application thereof.
Background
Shale gas development has entered the rapid development stage at present. The shale gas drilling fluid system commonly used at home and abroad mainly uses oil-based drilling fluid, and the oil-based drilling fluid has great advantages in maintaining the stability of shale stratum, has good lubricating property and pollution resistance, but has the environmental protection problems of high cost, large pollution, difficult treatment of drill cuttings and the like. At present, the water-based drilling fluid developed for shale stratum also has better application effects, such as: strong inhibition amine-based drilling fluid, silicate drilling fluid, organic or inorganic salt drilling fluid and the like, such as China patent CN104610941A, CN102250595A, CN102226076A, CN104610941A, CN103013470A, adopts polyamine and silicate inhibitors, has poor inhibition effect, is mostly polymer which is not easy to decompose, has poor biodegradability, and cannot meet the environmental protection requirement.
Disclosure of Invention
In view of the above, the invention aims to provide a shale gas green water-based drilling fluid and application thereof. The shale inhibition stabilizer in the water-based drilling fluid provided by the invention has good biodegradability and meets the environmental protection requirement.
In order to achieve the above object, the present invention provides the following technical solutions:
the invention provides a shale gas green water-based drilling fluid, which comprises water, bentonite, a tackifier, an alkalinity regulator, a shale inhibition stabilizer, a fluid loss additive, a shale blocking agent, a lubricant and a weighting material,
the weight of bentonite in the shale gas green water-based drilling fluid is 2.0-3.0 g, the weight of tackifier is 0.2-1.0 g, the weight of alkalinity regulator is 0.3-1.0 g, the weight of shale inhibition stabilizer is 20.0-40.0 g, the weight of filtrate reducer is 1.0-3.0 g, the weight of shale blocking agent is 2.0-5.0 g, the weight of lubricant is 2.0-4.0 g, and the weight of weighting material enables the density of the shale gas green water-based drilling fluid to be 1.2-2.0 g/cm 3 ；
The shale inhibition stabilizer comprises polyethylene glycol, sodium ethylenediamine tetramethylene phosphonate and sodium aminotrimethylene phosphonate.
Preferably, the shale inhibition stabilizer comprises the following components in parts by mass: 20 to 30 parts of polyethylene glycol, 30 to 40 parts of ethylenediamine tetramethylene sodium phosphonate and 30 to 50 parts of aminotrimethylene sodium phosphonate.
Preferably, the fluid loss additive comprises modified starch, carboxymethyl starch and polyanionic cellulose.
Preferably, the filtrate reducer comprises the following components in parts by mass: 45-60 parts of modified starch, 20-30 parts of carboxymethyl starch and 20-30 parts of polyanionic cellulose.
Preferably, the modified starch is prepared by a process comprising the steps of:
alkalizing starch to obtain alkalized starch;
mixing the alkalized starch and an etherifying agent for etherification reaction to obtain an etherified product;
mixing the etherification product with a silane coupling agent for crosslinking reaction to obtain a crosslinked product;
and regulating the pH value of the crosslinked product to 7 to obtain the modified starch.
Preferably, the etherifying agent is 3-chloro-2-hydroxypropyl trimethylammonium chloride or propylene oxide.
Preferably, the etherification reaction is carried out at a temperature of 70-80 ℃ for 2-3 hours.
Preferably, the mass ratio of the starch to the etherifying agent is 20-40: 6 to 9.
Preferably, the shale blocking agent comprises one or more of potassium humate, graphene oxide, nano silica and nano alumina.
The invention also provides application of the shale gas green water-based drilling fluid in the field of shale well section petroleum and natural gas drilling.
The invention provides a shale gas green water-based drilling fluid which comprises water, bentonite, a tackifier, an alkalinity regulator, a shale inhibition stabilizer, a fluid loss additive, a shale blocking agent, a lubricant and a weighting material, wherein the weight of the bentonite in the shale gas green water-based drilling fluid is 2.0-3.0 g, the weight of the tackifier is 0.2-1.0 g, the weight of the alkalinity regulator is 0.3-1.0 g, the weight of the shale inhibition stabilizer is 20.0-40.0 g, the weight of the fluid loss additive is 1.0-3.0 g, the weight of the shale blocking agent is 2.0-5.0 g, the weight of the lubricant is 2.0-4.0 g, and the weight of the weighting material enables the density of the shale gas green water-based drilling fluid to be 1.2-2.0 g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the The shale inhibition stabilizer comprises polyethylene glycol, sodium ethylenediamine tetramethylene phosphonate and sodium aminotrimethylene phosphonate.
Compared with the prior art, the invention has the following beneficial effects:
(1) All materials adopted by the invention are environment-friendly and biodegradable, and have small biological toxicity and environment-friendly property;
(2) The organic polyamine sodium phosphonate (ethylenediamine tetramethylene phosphonate) in the shale inhibition stabilizer adopted by the invention has extremely strong adsorption and good chelation, can be adsorbed in shale microcracks or pores to form good macromolecular network complex, and forms good plugging and wrapping effects under the action of high concentration to prevent microcracks from further disintegrating; the polyethylene glycol can further form a hydration film on the surface of the micro-crack, so that water is prevented from continuously penetrating into the micro-crack, and the stability of the well wall is facilitated;
(3) The shale blocking agent adopted by the invention can realize three-level blocking effect, not only can fill micro cracks on the surface of shale, but also can enable the formed blocking to be more compact by nano particles, and prevent deep invasion of filtrate;
(4) The shale gas green water-based drilling fluid has the characteristics of good rheological property, strong inhibition, low filtration loss and good lubricity, and the density range is 1.4-1.8 g/cm 3 Can meet the drilling requirements of most shale gas.
In conclusion, the shale gas green water-based drilling fluid provided by the invention has good rheological property, strong inhibition and lubricating performance, can keep the stability of the shale stratum well wall for a long time, reduces the drilling friction of the shale stratum, has good biodegradability and meets the environmental protection requirement.
Detailed Description
The invention provides a shale gas green water-based drilling fluid, which comprises water, bentonite, a tackifier, an alkalinity regulator, a shale inhibition stabilizer, a fluid loss additive, a shale blocking agent, a lubricant and a weighting material,
based on the volume of water of 100mL, the weight of bentonite in the shale gas green water-based drilling fluid is 2.0-3.0 g, the weight of tackifier is 0.2-1.0 g, the weight of alkalinity regulator is 0.3-1.0 g, the weight of shale inhibition stabilizer is 20.0-40.0 g, the weight of filtrate reducer is 1.0-3.0 g, the weight of shale blocking agent is 2.0-5.0 g,the weight of the lubricant is 2.0-4.0 g, and the weight of the weighting material ensures that the density of the shale gas green water-based drilling fluid is 1.2-2.0 g/cm 3 ；
The shale inhibition stabilizer comprises polyethylene glycol, sodium ethylenediamine tetramethylene phosphonate and sodium aminotrimethylene phosphonate.
In the present invention, all materials used are commercial products in the art unless otherwise specified.
The bentonite in the shale gas green water-based drilling fluid preferably weighs 2.5g, based on a volume of 100mL of water.
In the present invention, the bentonite is preferably sodium bentonite.
The weight of the tackifier in the shale gas green water-based drilling fluid is preferably 0.25-0.5 g, more preferably 0.3-0.4 g, based on the volume of water of 100 mL.
In the present invention, the tackifier is preferably xanthan gum.
The weight of the alkalinity regulator in the shale gas green water-based drilling fluid is 0.35-0.5 g, more preferably 0.4g, based on the volume of water of 100 mL.
In the present invention, the alkalinity regulator is preferably sodium carbonate and/or sodium hydroxide. When the alkalinity regulator is preferably a mixture of sodium carbonate and sodium hydroxide, the proportion of the substances in the mixture is not particularly limited in the present invention, and any mixture may be used.
The weight of the shale inhibition stabilizer in the shale gas green water-based drilling fluid is preferably 30-35 g based on the volume of water being 100 mL.
In the present invention, the shale inhibition stabilizer preferably comprises polyethylene glycol, sodium ethylenediamine tetramethylene phosphonate and sodium aminotrimethylene phosphonate.
In the invention, the shale inhibition stabilizer preferably comprises the following components in parts by mass: 20 to 30 parts of polyethylene glycol, 30 to 40 parts of ethylenediamine tetramethylene sodium phosphonate and 30 to 50 parts of aminotrimethylene sodium phosphonate. In a specific embodiment of the present invention, the rock suppression stabilizer is preferably the following components in parts by mass: 20 parts of polyethylene glycol, 30 parts of sodium ethylenediamine tetramethylene phosphonate and 50 parts of sodium aminotrimethylene phosphonate or 30 parts of polyethylene glycol, 35 parts of sodium ethylenediamine tetramethylene phosphonate and 35 parts of sodium aminotrimethylene phosphonate or the following components in parts by mass: 25 parts of polyethylene glycol, 30 parts of ethylenediamine tetramethylene sodium phosphonate and 40 parts of aminotrimethylene sodium phosphonate or the following components in parts by weight: 20 parts by weight of polyethylene glycol, 40 parts by weight of ethylenediamine tetramethylene phosphonate sodium and 40 parts by weight of aminotrimethylene phosphonate sodium.
The weight of the filtrate reducer in the shale gas green water-based drilling fluid is preferably 2-2.5 g based on the volume of water being 100 mL.
In the invention, the fluid loss additive preferably comprises modified starch, carboxymethyl starch and polyanionic cellulose, and more preferably comprises the following components in parts by mass: 45-60 parts of modified starch, 20-30 parts of carboxymethyl starch and 20-30 parts of polyanionic cellulose. In a specific embodiment of the invention, the fluid loss additive preferably comprises the following components in parts by mass: 50 parts of modified starch, 30 parts of carboxymethyl starch and 20 parts of polyanionic cellulose or 60 parts of modified starch, 20 parts of carboxymethyl starch and 20 parts of polyanionic cellulose or 45 parts of modified starch, 25 parts of carboxymethyl starch and 30 parts of polyanionic cellulose or 45 parts of modified starch, 30 parts of carboxymethyl starch and 25 parts of polyanionic cellulose.
In the present invention, the modified starch is preferably prepared by a process comprising the steps of:
alkalizing starch to obtain alkalized starch;
mixing the alkalized starch and an etherifying agent for etherification reaction to obtain an etherified product;
mixing the etherification product with a silane coupling agent for crosslinking reaction to obtain a crosslinked product;
and regulating the pH value of the crosslinked product to 7 to obtain the modified starch.
The invention alkalizes starch to obtain alkalized starch.
In the present invention, the starch is preferably corn starch.
The specific alkalization mode is not particularly limited, and a mode well known to a person skilled in the art is adopted, specifically, for example, corn starch is added into water and fully stirred until the starch is completely dispersed; dropwise adding sodium hydroxide solution as a catalyst, stirring for 30-50 min to fully alkalize the starch, and simultaneously introducing nitrogen into a reaction system to ensure that the reaction is carried out in an anaerobic environment.
After the alkalized starch is obtained, the alkalized starch and an etherifying agent are mixed for etherification reaction to obtain an etherified product.
In the present invention, the etherifying agent is preferably 3-chloro-2-hydroxypropyl trimethylammonium chloride or propylene oxide.
In the present invention, the temperature of the etherification reaction is preferably 70 to 80 ℃, and the time is preferably 2 to 3 hours, more preferably 2.5 hours.
In the invention, the mass ratio of the starch to the etherifying agent is preferably 20-40: 6 to 9, more preferably 20: 6. 30: 8. 40:9 or 35:8.
after the etherification product is obtained, the etherification product and the silane coupling agent are mixed for crosslinking reaction to obtain a crosslinked product.
In the present invention, the silane coupling agent is preferably γ -methacryloxypropyl trimethoxysilane (KH 570).
In the invention, the mass ratio of the starch to the silane coupling agent is preferably 20-40: 7 to 15, more preferably 20: 7. 30: 10. 40:15 or 35:10.
in the present invention, the temperature of the crosslinking reaction is preferably 70 to 80 ℃, and the time is preferably 3 to 4 hours, more preferably 3.5 hours.
After the crosslinking reaction is completed, the reaction system is preferably naturally cooled to room temperature to obtain the crosslinked product.
After the crosslinked product is obtained, the pH value of the crosslinked product is adjusted to 7, so that the modified starch is obtained.
The pH value is preferably adjusted to 7 by dilute hydrochloric acid.
After the pH value is adjusted, the modified starch is preferably obtained by sequentially drying and grinding.
In the present invention, the drying is preferably a drying, and the temperature of the drying is preferably 60 to 70 ℃ and the time is preferably 12 to 24 hours.
In the present invention, the grinding is preferably conducted by grinding through a 120 mesh screen.
The shale blocking agent in the shale gas green water-based drilling fluid preferably has a weight of 3-4 g, more preferably 3.5g, based on 100mL of water.
In the invention, the shale blocking agent preferably comprises one or more of potassium humate, graphene oxide, nano silicon dioxide and nano aluminum dioxide, more preferably comprises 30-45 parts by weight of potassium humate, 30-40 parts by weight of graphene oxide and 20-30 parts by weight of nano silicon dioxide, and in the specific embodiment of the invention, the shale blocking agent preferably comprises 30 parts by weight of potassium humate, 40 parts by weight of graphene oxide and 30 parts by weight of nano silicon dioxide or comprises 45 parts by weight of potassium humate, 30 parts by weight of graphene oxide and 25 parts by weight of nano silicon dioxide or comprises 35 parts by weight of potassium humate, 40 parts by weight of graphene oxide and 25 parts by weight of nano silicon dioxide or comprises 45 parts by weight of potassium humate, 35 parts by weight of graphene oxide and 20 parts by weight of nano silicon dioxide.
In the present invention, the particle size of the graphene oxide is preferably 10 to 50 μm, and the particle size of the nano silica is preferably 30 to 70 nm.
The weight of the lubricant in the shale gas green water-based drilling fluid is preferably 3g based on the volume of water of 100 mL.
In the invention, the lubricant preferably comprises one or more of vegetable oil, graphite powder and extreme pressure lubricant, and the lubricant not only can form an oil film effect on a well wall and improve the contact state of a drilling tool and the well wall, but also can change rolling friction into sliding friction by adding the graphite powder, thereby greatly improving the lubricating effect.
The weight of the weighting material in the shale gas green water-based drilling fluid is calculated by taking the volume of the water as 100mL, so that the density of the shale gas green water-based drilling fluid is preferably 1.4-1.8 g/cm 3 。
In the present invention, whatThe weighting material is preferably barite, and the density of the barite is preferably 4.2-4.4 g/cm 3 。
The preparation method of the shale gas green water-based drilling fluid is not particularly limited, and the shale gas green water-based drilling fluid is prepared by a preparation method of a composition well known to a person skilled in the art.
The invention also provides application of the shale gas green water-based drilling fluid in the field of shale well section petroleum and natural gas drilling.
The specific mode of the application of the present invention is not particularly limited, and modes well known to those skilled in the art can be adopted.
For further explanation of the present invention, the shale gas green water-based drilling fluids and applications thereof provided herein are described in detail below with reference to examples, but they should not be construed as limiting the scope of the invention.
(1) The "GB/T16783.1-2014" Petroleum and Natural gas industry drilling fluid field test part 1: water-based drilling fluid "methods and instruments for determining the density of drilling fluid;
(2) The "GB/T16783.1-2014" Petroleum and Natural gas industry drilling fluid field test part 1: the method and instrument specified in water-based drilling fluid are used for measuring the plastic viscosity of the drilling fluid;
(3) The "GB/T16783.1-2014" Petroleum and Natural gas industry drilling fluid field test part 1: the method and instrument specified in water-based drilling fluid are used for measuring the dynamic shear force of the drilling fluid;
(4) The "GB/T16783.1-2014" Petroleum and Natural gas industry drilling fluid field test part 1: measuring the API fluid loss of the drilling fluid and the high-temperature high-pressure fluid loss by using a method and an instrument specified in the water-based drilling fluid;
(5) Determining the inhibition performance of the shale inhibition stabilizer and the drilling fluid by adopting a method and an instrument specified in ' NB/T10121-2018 ' method for evaluating shale inhibition performance of the drilling fluid ';
(6) The lubricating performance of the high-temperature-resistant environment-friendly lubricant and the drilling fluid is measured by adopting a method and an instrument specified in Q-SY 17088-2016 technical Specification of liquid lubricants for drilling fluids;
(7) The biotoxicity of the drilling fluid is measured by adopting a method and an instrument specified in SY/T67882020 environmental protection technical evaluation requirement of water-soluble oil field chemical agent.
Example 1
The concrete preparation steps of the filtrate reducer are as follows:
(1) Adding 100 parts by weight of water into a four-necked flask, adding 20 parts by weight of corn starch while stirring, fully stirring until the starch is completely dispersed, then dropwise adding 3 parts by weight of sodium hydroxide as a catalyst, stirring for 30min to fully alkalize the starch, and simultaneously introducing nitrogen into the four-necked flask to ensure that the reaction is carried out in an anaerobic environment; heating to 70 ℃, adding 6 parts by weight of propylene oxide as an etherifying agent, and carrying out etherification reaction for 2 hours at constant temperature; then adding 7 parts by weight of KH570, continuously stirring at constant temperature to perform crosslinking reaction, and reacting for 3h; and naturally cooling to room temperature after the reaction is finished, regulating the pH value of the reaction product to 7 by using dilute hydrochloric acid, drying for 12 hours at 60 ℃ to obtain the reaction product, grinding the reaction product, and sieving the ground reaction product with a 120-mesh sieve to obtain the modified starch.
(2) And uniformly mixing 50 parts by weight of the synthesized modified starch, 30 parts by weight of carboxymethyl starch and 20 parts by weight of polyanionic cellulose to obtain the filtrate reducer.
And uniformly mixing 20 parts by weight of polyethylene glycol, 30 parts by weight of ethylenediamine tetramethylene sodium phosphonate and 50 parts by weight of aminotrimethylene sodium phosphonate to obtain the shale inhibition stabilizer.
And uniformly mixing 30 parts by weight of potassium humate, 40 parts by weight of graphene oxide (with the particle size of 10-50 microns) and 30 parts by weight of nano silicon dioxide (with the particle size of 30-70 nanometers) to obtain the shale blocking agent.
The shale gas green water-based drilling fluid of the embodiment is composed of the following components in parts by weight based on the total volume of the water of 100 mL:
bentonite (sodium bentonite): 2.0g;
tackifier (xanthan gum): 0.3g;
alkalinity regulator (sodium hydroxide): 0.3g;
shale inhibition stabilizer: 20.0g;
filtrate reducer: 1.0g;
shale blocking agent: 2.0g;
lubricant (vegetable oil): 2.0g;
weighting material (barite): weighting to 1.2g/cm 3 ；
The preparation method of the shale gas green water-based drilling fluid comprises the following steps: weighing 400mL of water in a 1000mL high-stirring cup, adding 8.0g of sodium bentonite at a rotating speed of 6000r/min, and stirring at a high speed for 20min; then adding 1.2g of sodium hydroxide, and stirring at a high speed for 20min; adding 1.2g of xanthan gum, and stirring at 8000r/min for 20min; adding 80.0g shale inhibition stabilizer, and stirring at high speed for 20min; adding 4.0g of filtrate reducer, and stirring at high speed for 20min; 8.0g of shale blocking agent is added, and the mixture is stirred at a high speed for 20min; adding 8.0g vegetable oil, and stirring at high speed for 20min; finally, adding barite to increase the density of the drilling fluid to 1.2g/cm 3 Stirring at high speed for 30min.
Example 2
The concrete preparation steps of the filtrate reducer are as follows:
(1) 150 parts by weight of water and 30 parts by weight of corn starch are added into a four-neck flask while stirring, 4 parts by weight of sodium hydroxide is dropwise added as a catalyst after the starch is fully dispersed, stirring is carried out for 40min to fully alkalize the starch, and meanwhile, nitrogen is introduced into the four-neck flask to ensure that the reaction is carried out in an anaerobic environment; heating to 80 ℃, adding 8 parts by weight of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride as an etherifying agent, and carrying out etherification reaction at constant temperature for 2.5 hours; then adding 10 parts by weight of KH570, and continuing stirring at constant temperature to perform crosslinking reaction for 3.5h; and naturally cooling to room temperature after the reaction is finished, regulating the pH value of the reaction product to 7 by using dilute hydrochloric acid, drying for 20 hours at 70 ℃ to obtain the reaction product, grinding the reaction product, and sieving the ground reaction product with a 120-mesh sieve to obtain the modified starch.
(2) And (3) uniformly mixing 60 parts by weight of the synthesized modified starch, 20 parts by weight of carboxymethyl starch and 20 parts by weight of polyanionic cellulose to obtain the filtrate reducer.
And uniformly mixing 30 parts by weight of polyethylene glycol, 35 parts by weight of ethylenediamine tetramethylene phosphonate and 35 parts by weight of aminotrimethylene phosphonate to obtain the shale inhibition stabilizer.
And uniformly mixing 45 parts by weight of potassium humate, 30 parts by weight of graphene oxide (with the particle size of 10-50 microns) and 25 parts by weight of nano silicon dioxide (with the particle size of 30-70 nanometers) to obtain the shale blocking agent.
The shale gas green water-based drilling fluid of the embodiment is composed of the following components in parts by weight based on the total volume of the water of 100 mL:
bentonite (sodium bentonite): 3.0g;
tackifier (xanthan gum): 0.4g;
alkalinity regulator (sodium hydroxide): 0.5g;
shale inhibition stabilizer: 30.0g;
filtrate reducer: 2.0g;
shale blocking agent: 3.0g;
lubricant (vegetable oil, graphite powder): 3.0g;
weighting material (barite): weighting to 1.4g/cm 3 ；
The preparation method of the shale gas green water-based drilling fluid comprises the following steps: weighing 400mL of water in a 1000mL high-stirring cup, adding 12.0g of sodium bentonite at a rotating speed of 6000r/min, and stirring at a high speed for 20min; then adding 2.0g of sodium hydroxide, and stirring at a high speed for 20min; adding 1.6g of xanthan gum, and stirring at 8000r/min for 20min; adding 120.0g of shale inhibition stabilizer, and stirring at a high speed for 20min; adding 8.0g of filtrate reducer, and stirring at high speed for 20min; adding 12.0g of shale blocking agent, and stirring at a high speed for 20min; adding 6.0g of vegetable oil and 6.0g of graphite powder, and stirring at a high speed for 20min; finally, adding barite to increase the density of the drilling fluid to 1.4g/cm 3 Stirring at high speed for 30min.
Example 3
The preparation method of the filtrate reducer comprises the following specific steps:
(1) Adding 200 parts by weight of water into a four-necked flask, adding 40 parts by weight of corn starch while stirring, fully stirring until the starch is completely dispersed, then dropwise adding 5 parts by weight of sodium hydroxide as a catalyst, stirring for 50min to fully alkalize the starch, and simultaneously introducing nitrogen into the four-necked flask to ensure that the reaction is carried out in an anaerobic environment; heating to 80 ℃, adding 9 parts by weight of propylene oxide as an etherifying agent, and carrying out etherification reaction for 3 hours at constant temperature; then adding 15 parts by weight of KH570, and continuing to stir at constant temperature to perform crosslinking reaction for 3.5h; and naturally cooling to room temperature after the reaction is finished, regulating the pH value of the reaction product to 7 by using dilute hydrochloric acid, drying for 22 hours at 70 ℃ to obtain the reaction product, grinding the reaction product, and sieving the ground reaction product with a 120-mesh sieve to obtain the modified starch.
(2) And (3) uniformly mixing 45 parts of the synthesized modified starch, 30 parts of carboxymethyl starch and 25 parts of polyanionic cellulose to obtain the filtrate reducer.
And uniformly mixing 25 parts by weight of polyethylene glycol, 35 parts by weight of ethylenediamine tetramethylene sodium phosphonate and 40 parts by weight of aminotrimethylene sodium phosphonate to obtain the shale inhibition stabilizer.
And uniformly mixing 35 parts by weight of potassium humate, 40 parts by weight of graphene oxide (with the particle size of 10-50 microns) and 25 parts by weight of nano silicon dioxide (with the particle size of 30-70 nanometers) to obtain the shale blocking agent.
The shale gas green water-based drilling fluid of the embodiment is composed of the following components in parts by weight based on the total volume of the water of 100 mL:
bentonite (sodium bentonite): 3.0g;
tackifier (xanthan gum): 0.25g;
alkalinity regulator (sodium hydroxide): 0.35g;
shale inhibition stabilizer: 35.0g;
filtrate reducer: 2.5g;
shale blocking agent: 3.5g;
lubricant (extreme pressure lubricant): 3.0g;
weighting material (barite): weighting to 2.0g/cm 3 ；
The preparation method of the shale gas green water-based drilling fluid comprises the following steps: weighing 400mL of water in a 1000mL high-stirring cup, adding 12.0g of sodium bentonite at a rotating speed of 6000r/min, and stirring at a high speed for 20min; then adding 1.4g of sodium hydroxide, and stirring at a high speed for 20min; adding 1.0g of xanthan gum, and stirring at 8000r/min for 20min; adding 140.0g shale inhibition stabilizer, and stirring at high speed for 20min; adding 10.0g of filtrate reducer, and stirring at high speed for 20min; 14.0g of shale blocking agent is added, the height is highStirring at a high speed for 20min; adding 12.0g of extreme pressure lubricant, and stirring at high speed for 20min; finally adding barite to increase the density of the drilling fluid to 2g/cm 3 Stirring at high speed for 30min.
Example 4
The preparation method of the filtrate reducer comprises the following specific steps:
(1) Adding 175 parts by weight of water into a four-necked flask, adding 35 parts by weight of corn starch while stirring, fully stirring until the starch is completely dispersed, then dropwise adding 4 parts by weight of sodium hydroxide as a catalyst, stirring for 50min to fully alkalize the starch, and simultaneously introducing nitrogen into the four-necked flask to ensure that the reaction is carried out in an anaerobic environment; heating to 80 ℃, adding 8 parts by weight of propylene oxide as an etherifying agent, and carrying out etherification reaction for 3 hours at constant temperature; then adding 10 parts by weight of KH570, continuously stirring at constant temperature to perform crosslinking reaction, and reacting for 4 hours; and naturally cooling to room temperature after the reaction is finished, regulating the pH value of the reaction product to 7 by using dilute hydrochloric acid, drying for 24 hours at 70 ℃ to obtain the reaction product, grinding the reaction product, and sieving the ground reaction product with a 120-mesh sieve to obtain the modified starch.
(2) And (3) uniformly mixing 45 parts of the synthesized modified starch, 25 parts of carboxymethyl starch and 30 parts of polyanionic cellulose to obtain the filtrate reducer.
And uniformly mixing 20 parts by weight of polyethylene glycol, 40 parts by weight of ethylenediamine tetramethylene sodium phosphonate and 40 parts by weight of aminotrimethylene sodium phosphonate to obtain the shale inhibition stabilizer.
And uniformly mixing 45 parts by weight of potassium humate, 35 parts by weight of graphene oxide (with the particle size of 10-50 microns) and 20 parts by weight of nano silicon dioxide (with the particle size of 30-70 nanometers) to obtain the shale blocking agent.
The shale gas green water-based drilling fluid of the embodiment is composed of the following components in parts by weight based on the total volume of the water of 100 mL:
bentonite (sodium bentonite): 3.0g;
tackifier (xanthan gum): 0.5g;
alkalinity regulator (sodium carbonate, sodium hydroxide): 0.4g;
shale inhibition stabilizer: 40.0g;
filtrate reducer: 3.0g;
shale blocking agent: 4.0g;
lubricant (extreme pressure lubricant): 3.0g;
weighting material (barite): weighting to 1.8g/cm3;
the preparation method of the shale gas green water-based drilling fluid comprises the following steps: weighing 400mL of water in a 1000mL high-stirring cup, adding 12.0g of sodium bentonite at a rotating speed of 6000r/min, and stirring at a high speed for 20min; then adding 1.0g of sodium hydroxide and 0.6g of sodium carbonate, and stirring at a high speed for 20min; adding 2.0g of xanthan gum, and stirring at 8000r/min for 20min; 160.0g of shale inhibition stabilizer is added and stirred at high speed for 20min; adding 12.0g of filtrate reducer, and stirring at high speed for 20min; adding 16.0g of shale blocking agent, and stirring at a high speed for 20min; adding 12.0g of extreme pressure lubricant, and stirring at high speed for 20min; finally adding barite to increase the density of the drilling fluid to 1.8g/cm 3 Stirring at high speed for 30min.
Table 1 shows the inhibition performance of the shale inhibition stabilizers of examples 1 to 3, and as can be seen from the data of examples 1 to 3 of table 1, the shale inhibition stabilizers of the present invention all have a rolling recovery rate of 98% or more, a linear expansion rate of 45% or more, and a slurry production reduction rate of more than 97%, and exhibit good shale inhibition performance.
Table 2 shows the basic performances of the shale green water-based drilling fluids of examples 1-4, and the data of examples 1, 2, 3 and 4 in Table 2 show that the shale gas green water-based drilling fluid has the characteristics of low water loss at high temperature and high pressure, strong plugging inhibition, good lubricity, low toxicity and good degradability under different density conditions.
Table 1 examples 1-3 inhibition performance of shale inhibition stabilizers
| Test specimen | Rolling recovery/% | Linear expansion rate/% | Reduction rate of pulping/% |
| Example 1 | 98.33 | 46.78 | 97.35 |
| Example 2 | 98.49 | 45.85 | 98.08 |
| Example 3 | 99.02 | 46.59 | 97.96 |
Table 2 basic properties of green shale gas green water-based drilling fluids for each shale of examples 1-4
| Drilling fluid | ρ | AV | PV | YP | FL API | FL HTHP | M | GD | EC 50 | BOD 5 /COD cr |
| Example 1 | 1.2 | 32 | 23 | 9 | 3.6 | 11.2 | 0.08 | 95.62 | 82000 | 58.2 |
| Example 2 | 1.4 | 36 | 26 | 9 | 3.4 | 10.8 | 0.09 | 95.85 | 84000 | 59.4 |
| Example 3 | 1.6 | 45 | 35 | 10 | 3.2 | 10.2 | 0.11 | 96.21 | 87000 | 61.5 |
| Example 4 | 1.8 | 58 | 37 | 11 | 3.0 | 9.8 | 0.08 | 96.45 | 89000 | 65.3 |
Note that: thermal rolling conditions: 120 ℃ x 16h, hthp water loss assay conditions: 3.5MPa multiplied by 120 ℃;
ρ: density of drilling fluid, g/cm 3 ；
AV: apparent viscosity of drilling fluid, mPa.s;
PV: plastic viscosity of drilling fluid, mPa.s;
YP: drilling fluid cutting force Pa;
API: drilling fluid medium-pressure water loss (0.7 MPa, T,30 min), mL;
FL HTHP : drilling fluid is dehydrated at high temperature and high pressure (3.5 MPa, T,30 min) and mL;
EC 50 : biotoxicity by a luminescent bacterial method, and mg/L;
m: friction coefficient of drilling fluid, dimensionless;
and GD: rolling recovery,%;
BOD 5 /COD cr : biodegradability of drilling fluid,%.
The foregoing is merely a preferred embodiment of the present invention and is not intended to limit the present invention in any way. It should be noted that modifications and adaptations to the present invention may occur to one skilled in the art without departing from the principles of the present invention and are intended to be comprehended within the scope of the present invention.
Claims (10)
1. A shale gas green water-based drilling fluid is characterized by comprising water, bentonite, a tackifier, an alkalinity regulator, a shale inhibition stabilizer, a fluid loss additive, a shale blocking agent, a lubricant and a weighting material,
the weight of bentonite in the shale gas green water-based drilling fluid is 2.0-3.0 g, the weight of tackifier is 0.2-1.0 g, the weight of alkalinity regulator is 0.3-1.0 g, the weight of shale inhibition stabilizer is 20.0-40.0 g, the weight of filtrate reducer is 1.0-3.0 g, the weight of shale blocking agent is 2.0-5.0 g, the weight of lubricant is 2.0-4.0 g, and the weight of weighting material enables the density of the shale gas green water-based drilling fluid to be 1.2-2.0 g/cm 3 ；
The shale inhibition stabilizer comprises polyethylene glycol, sodium ethylenediamine tetramethylene phosphonate and sodium aminotrimethylene phosphonate.
2. The shale gas green water-based drilling fluid according to claim 1, wherein the shale inhibition stabilizer comprises the following components in parts by mass: 20 to 30 parts of polyethylene glycol, 30 to 40 parts of ethylenediamine tetramethylene sodium phosphonate and 30 to 50 parts of aminotrimethylene sodium phosphonate.
3. The shale gas green water-based drilling fluid of claim 1, wherein the fluid loss additive comprises modified starch, carboxymethyl starch, and polyanionic cellulose.
4. The shale gas green water-based drilling fluid according to claim 3, wherein the filtrate reducer comprises the following components in parts by mass: 45-60 parts of modified starch, 20-30 parts of carboxymethyl starch and 20-30 parts of polyanionic cellulose.
5. The shale gas green water-based drilling fluid of claim 3 or 4, wherein the modified starch is prepared by a process comprising the steps of:
alkalizing starch to obtain alkalized starch;
mixing the alkalized starch and an etherifying agent for etherification reaction to obtain an etherified product;
mixing the etherification product with a silane coupling agent for crosslinking reaction to obtain a crosslinked product;
and regulating the pH value of the crosslinked product to 7 to obtain the modified starch.
6. The shale gas green water-based drilling fluid of claim 5, wherein the etherifying agent is 3-chloro-2-hydroxypropyl trimethylammonium chloride or propylene oxide.
7. The shale gas green water-based drilling fluid according to claim 5, wherein the etherification reaction is carried out at a temperature of 70-80 ℃ for 2-3 hours.
8. The shale gas green water-based drilling fluid according to claim 1, wherein the mass ratio of the starch to the etherifying agent is 20-40: 6 to 9.
9. The shale gas green water-based drilling fluid of claim 1, wherein the shale blocking agent comprises one or more of potassium humate, graphene oxide, nano-silica, and nano-alumina.
10. Use of the shale gas green water-based drilling fluid according to any of claims 1-9 in the field of shale well section oil and gas drilling.
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