CN117946642A - Inhibitory water-based foam drilling fluid system - Google Patents
Inhibitory water-based foam drilling fluid system Download PDFInfo
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- CN117946642A CN117946642A CN202211285736.9A CN202211285736A CN117946642A CN 117946642 A CN117946642 A CN 117946642A CN 202211285736 A CN202211285736 A CN 202211285736A CN 117946642 A CN117946642 A CN 117946642A
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- Prior art keywords
- water
- drilling fluid
- fluid system
- inhibitor
- foam
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- 239000006260 foam Substances 0.000 title claims abstract description 46
- 238000005553 drilling Methods 0.000 title claims abstract description 40
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 37
- 239000012530 fluid Substances 0.000 title claims abstract description 24
- 230000002401 inhibitory effect Effects 0.000 title claims abstract description 14
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical compound FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 claims abstract description 26
- 239000003112 inhibitor Substances 0.000 claims abstract description 21
- 239000004094 surface-active agent Substances 0.000 claims abstract description 20
- 239000003381 stabilizer Substances 0.000 claims abstract description 19
- 239000004088 foaming agent Substances 0.000 claims abstract description 16
- 239000000203 mixture Substances 0.000 claims abstract description 14
- 239000000440 bentonite Substances 0.000 claims abstract description 13
- 229910000278 bentonite Inorganic materials 0.000 claims abstract description 13
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims abstract description 13
- 229920002401 polyacrylamide Polymers 0.000 claims abstract description 10
- 238000000034 method Methods 0.000 claims abstract description 4
- 229920002472 Starch Polymers 0.000 claims abstract description 3
- 239000001913 cellulose Substances 0.000 claims abstract description 3
- 229920002678 cellulose Polymers 0.000 claims abstract description 3
- 239000008107 starch Substances 0.000 claims abstract description 3
- 235000019698 starch Nutrition 0.000 claims abstract description 3
- 238000003756 stirring Methods 0.000 claims description 14
- -1 quaternary ammonium salt cations Chemical class 0.000 claims description 8
- VILCJCGEZXAXTO-UHFFFAOYSA-N 2,2,2-tetramine Chemical compound NCCNCCNCCN VILCJCGEZXAXTO-UHFFFAOYSA-N 0.000 claims description 5
- RPNUMPOLZDHAAY-UHFFFAOYSA-N Diethylenetriamine Chemical compound NCCNCCN RPNUMPOLZDHAAY-UHFFFAOYSA-N 0.000 claims description 4
- 150000003242 quaternary ammonium salts Chemical class 0.000 claims description 4
- FAGUFWYHJQFNRV-UHFFFAOYSA-N tetraethylenepentamine Chemical compound NCCNCCNCCNCCN FAGUFWYHJQFNRV-UHFFFAOYSA-N 0.000 claims description 4
- 238000002360 preparation method Methods 0.000 claims description 3
- 229910020596 CmF2m+1SO2 Inorganic materials 0.000 claims description 2
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 claims description 2
- 229920002521 macromolecule Polymers 0.000 claims description 2
- 229910052901 montmorillonite Inorganic materials 0.000 claims description 2
- 239000006265 aqueous foam Substances 0.000 claims 3
- 125000001453 quaternary ammonium group Chemical group 0.000 claims 1
- 230000005764 inhibitory process Effects 0.000 abstract description 5
- 238000005187 foaming Methods 0.000 abstract description 2
- 239000000047 product Substances 0.000 description 14
- 238000004090 dissolution Methods 0.000 description 6
- 239000011435 rock Substances 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- 230000036571 hydration Effects 0.000 description 5
- 238000006703 hydration reaction Methods 0.000 description 5
- 239000004604 Blowing Agent Substances 0.000 description 4
- 229960001124 trientine Drugs 0.000 description 4
- 238000011084 recovery Methods 0.000 description 3
- 230000032683 aging Effects 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000005096 rolling process Methods 0.000 description 2
- 239000000523 sample Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 238000005303 weighing Methods 0.000 description 2
- 208000010392 Bone Fractures Diseases 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 206010017076 Fracture Diseases 0.000 description 1
- 239000012752 auxiliary agent Substances 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 125000002091 cationic group Chemical group 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000005098 hot rolling Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 239000012488 sample solution Substances 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 238000007873 sieving Methods 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
- 239000002562 thickening agent Substances 0.000 description 1
Landscapes
- Emulsifying, Dispersing, Foam-Producing Or Wetting Agents (AREA)
Abstract
The invention discloses an inhibitory water-based foam drilling fluid system, which solves the problem of instability of a well wall in the prior foam drilling. The system comprises 0.5% -1.0% of fluorocarbon surfactant, 0.2% -1.0% of inhibitor, 0.04% -0.2% of foam stabilizer, 0.2% -0.4% of tackifier, 1.0% -5.0% of bentonite and the balance of water, wherein the fluorocarbon surfactant is fluorocarbon surfactant containing quaternary ammonium salt cation structure, the inhibitor is inhibitor of small molecular amine salt structure, and the macromolecular foam stabilizer is one or more compositions of starch, cellulose and polyacrylamide. The foaming agent provided by the invention is applied to the foam drilling process, and has stronger foaming performance and strong inhibition performance.
Description
Technical Field
The invention relates to a chemical auxiliary agent for drilling, in particular to an inhibitory water-based foam drilling fluid system, which belongs to the field of treating agents for oilfield drilling fluid and relates to the drilling, completion, well repair and oil-gas well yield increasing measures of large-size ultra-long open hole wells and horizontal wells.
Background
After the gas drilling meets the stratum water outlet, a corresponding treatment mode is adopted according to the different water outlet amount. However, in field application, because water blocking or water absorbing operation is often not satisfactory, gas drilling is generally converted into foam drilling, and compared with conventional drilling fluid drilling, the foam drilling fluid has unique advantages in the aspects of protecting hydrocarbon reservoir, preventing stratum leakage and the like, solves the stratum water outlet problem in gas drilling, and greatly improves the effective supplement of mechanical drilling speed. Compared with pure gas drilling, the foam fluid has high viscosity and shear force and strong suspending and rock carrying capacity, can effectively solve the technical problem that the gas drilling can not be smoothly constructed when meeting stratum water, and is one of more ideal drilling technologies for oil and gas reservoir exploration and development of fracture reservoirs with larger leakage amount, pressure failure stratum, low-pressure low-permeability stratum and the like. However, a great amount of sewage can be generated in the drilling process of the conventional water-based foam drilling fluid system, so that on one hand, the drilling fluid has a certain promotion effect on shale hydration, the shale hydration promotes the viscosity of the foam base fluid to be fast, and clear water and drilling materials need to be supplemented; on the other hand, the treatment cost is very high. This is mainly due to the fact that the drilling fluid system is not strong in shale hydration inhibition performance. The development of the inhibitory water-based foam drilling fluid system can inhibit the hydration of shale and improve the utilization rate of foam base fluid, and has very remarkable significance.
Disclosure of Invention
In order to overcome the defects of the prior art, one of the purposes of the invention is to provide a foaming agent system with strong inhibition performance and simple composition for solving the problem of well instability in foam drilling.
The invention relates to an inhibitory water-based foam drilling fluid system, which comprises fluorocarbon foaming agent, inhibitor, foam stabilizer, tackifier, bentonite and water, wherein the weight ratio of the components is as follows: 0.5 to 1.0 percent of fluorocarbon foaming agent, 0.2 to 1.0 percent of inhibitor, 0.04 to 0.2 percent of foam stabilizer, 0.2 to 0.4 percent of tackifier, 1.0 to 5.0 percent of bentonite and the balance of water;
the fluorocarbon foaming agent is fluorocarbon surfactant containing quaternary ammonium salt cations;
the inhibitor is an inhibitor containing a small-molecule amine salt structure;
the foam stabilizer is a macromolecular substance foam stabilizer and is one or more compositions selected from starch, cellulose and polyacrylamide;
the tackifier is a tackifier treated by quaternary ammonium salt surfactant.
The fluorocarbon surfactant containing quaternary ammonium salt cations has a molecular structural formula as follows:
CmF2m+1SO2NH(CH2)3N+(CnH2n+1)3I-
wherein: m=6 to 10, n=1 to 3.
The small molecular amine salt inhibitor is selected from one or a combination of diethylenetriamine, triethylenetetramine and tetraethylenepentamine.
The tackifier is a water delivery modified tackifier formed by treating montmorillonite with a quaternary ammonium salt surfactant.
The composition of the quaternary ammonium salt cationic fluorocarbon surfactant is preferably m=6-8, and n=1-2.
The invention also provides a preparation method of the inhibitory water-based foam drilling fluid system, which comprises the following preparation steps: firstly, adding a fluorocarbon foaming agent into half of water, slowly stirring until the fluorocarbon foaming agent is completely dissolved, then adding an inhibitor into the other half of water, slowly stirring until the fluorocarbon foaming agent is completely dissolved, finally, mixing the two solutions, sequentially adding a foam stabilizer, a tackifier and bentonite while stirring, and slowly and uniformly stirring.
The application field of the inhibitory water-based foam drilling fluid system provided by the invention is the field of oilfield drilling, and is suitable for the stratum with frequent upper stratum sand-mud rock interbedding, high hardness, high grindability and poor drillability and the low-pressure stratum with poor well wall stability.
The invention has the advantages that the fluorocarbon surfactant with a specific molecular structure is adopted to enhance the foam performance of the system, the small molecular amine salt has a strong effect of inhibiting the hydration of shale, and the thickening agent and the foam stabilizer can enhance the suspension effect and the rock carrying capacity of the system, thereby achieving the effects of inhibiting collapse, suspending and carrying rock and fast drilling.
Compared with the prior art, the invention has the following excellent effects:
(1) The foaming agent system can have stronger foaming performance and strong inhibition performance at the same time;
(2) The temperature resistance of the foaming agent can reach 150 ℃, and the half life of the foam can reach more than 50 min.
Detailed Description
The invention is further illustrated by the following examples, which are intended only for a better understanding of the invention and are not intended to limit the atmosphere in which the invention is protected.
Example 1:
Under the room temperature condition, slowly adding 0.5g of fluorocarbon surfactant (m=8, n=1) into a beaker containing 98.06g of water, stirring and adding, after complete dissolution, slowly adding 0.2g of inhibitor diethylenetriamine, 0.04g of polyacrylamide foam stabilizer, 0.2g of tackifier and 1.0g of bentonite in sequence, and stirring for 0.5h to obtain the product No. 1.
Example 2:
Under the room temperature condition, 1.0g of fluorocarbon surfactant (m=8, n=2) is slowly added into a beaker containing 92.9g of water, the mixture is stirred and added, after the mixture is completely dissolved, 0.5g of inhibitor tetraethylenepentamine, 0.2g of polyacrylamide foam stabilizer, 0.4g of tackifier and 5.0g of bentonite are slowly added in sequence, and the mixture is stirred for 0.5h, so that the product No.2 is obtained.
Example 3:
Under the room temperature condition, 1.0g of fluorocarbon surfactant (m=6, n=1) is slowly added into a beaker containing 95.6g of water, the mixture is stirred and added, after complete dissolution, 1.0g of triethylene tetramine as an inhibitor, 0.1g of polyacrylamide foam stabilizer, 0.3g of tackifier and 2.0g of bentonite are slowly added in sequence, and the mixture is stirred for 0.5h, thus obtaining the product 3#.
Example 4:
Under the room temperature condition, 1.0g of fluorocarbon surfactant (m=8, n=2) is slowly added into a beaker containing 93.6g of water, the mixture is stirred and added, after complete dissolution, 1.0g of inhibitor diethylenetriamine, 0.1g of polyacrylamide foam stabilizer, 0.3g of tackifier and 4.0g of bentonite are slowly added in sequence, and the mixture is stirred for 0.5h, thus obtaining the product No. 4.
Example 5:
Under the room temperature condition, slowly adding 0.5g of fluorocarbon surfactant (m=8, n=2) into a beaker containing 93.1g of water, stirring and adding, after complete dissolution, slowly adding 0.8g of triethylene tetramine serving as an inhibitor, 0.2g of polyacrylamide foam stabilizer, 0.4g of tackifier and 5.0g of bentonite in sequence, and stirring for 0.5h to obtain the product No. 5.
Example 6:
Under the room temperature condition, slowly adding 0.8g of fluorocarbon surfactant (m=6, n=2) into a beaker containing 95.06g of water, stirring and adding, after complete dissolution, slowly adding 0.8g of inhibitor tetraethylenepentamine, 0.04g of polyacrylamide foam stabilizer, 0.3g of tackifier and 3.0g of bentonite in sequence, and stirring for 0.5h to obtain the product No. 6.
Example 7:
Under the room temperature condition, 1.0g of fluorocarbon surfactant (m=8, n=2) is slowly added into a beaker containing 93.6g of water, the mixture is stirred and added, after complete dissolution, 1.0g of triethylene tetramine as an inhibitor, 0.1g of polyacrylamide foam stabilizer, 0.3g of tackifier and 4.0g of bentonite are slowly added in sequence, and the mixture is stirred for 0.5h, thus obtaining the product No. 7.
Example 8: evaluation of blowing agent System Properties
Foam properties of the blowing agent system: 100g of the above sample was poured into a stirring cup, stirred at 11000rpm for 1min, and after the stirring was stopped, the timing was started, the foam was poured into a measuring cylinder, the foam volume was measured, and the time taken to precipitate 50nL of liquid (liquid-separating half-life) was recorded.
Inhibition properties of the blowing agent system: core rolling recovery rate of shale in clear water and foaming agent solution is tested by referring to a standard SY-T5613-2000 shale physical and chemical property test method. The method comprises the following specific steps: weighing 20.0g of 4-8 mesh core, adding into a high-temperature aging kettle, adding the sample solution system of 350 mL into the aging kettle, hot rolling at 150 ℃ for 16 hours, sieving the core with a 100 mesh sieve, drying the sieved material at 105 ℃ for 4 hours, cooling to room temperature in a dryer, and weighing. The ratio of the weight of the recovered rock debris to the weight of the initial rock debris is the primary core recovery rate.
TABLE 1 results of evaluation of blowing agent Properties
| Sample of | Foam volume/mL | Half-life/min of liquid separation | Rolling recovery/% |
| Clean water | / | / | 11.70 |
| Commercially available inhibiting foaming agents | 495 | 7.8 | 24.60 |
| Product #1 | 575 | 57 | 68.90 |
| Product #2 | 540 | 64 | 72.45 |
| 3# Product | 530 | 56 | 81.02 |
| Product #4 | 560 | 59 | 64.92 |
| Product # 5 | 570 | 68 | 59.06 |
| Product # 6 | 555 | 73 | 72.38 |
| Product # 7 | 515 | 57 | 67.14 |
Claims (7)
1. The inhibitive water-based foam drilling fluid system is characterized by comprising the following components in percentage by weight:
0.5 to 1.0 percent of fluorocarbon foaming agent
0.2 To 1.0 percent of inhibitor
Foam stabilizer 0.04-0.2%
0.2 To 0.4 percent of tackifier
Bentonite 1.0-5.0%
The balance of water;
the fluorocarbon foaming agent is fluorocarbon surfactant containing quaternary ammonium salt cations;
the inhibitor is an inhibitor containing a small-molecule amine salt structure;
the foam stabilizer is a macromolecular substance foam stabilizer and is one or more compositions selected from starch, cellulose and polyacrylamide;
the tackifier is a tackifier treated by quaternary ammonium salt surfactant.
2. The inhibited aqueous foam drilling fluid system of claim 1 wherein said fluorocarbon surfactant containing quaternary ammonium salt cations has the molecular structural formula:
CmF2m+1SO2NH(CH2)3N+(CnH2n+1)3I-
wherein: m=6 to 10, n=1 to 3.
3. The inhibited aqueous foam drilling fluid system of claim 1 wherein said small molecule amine salt inhibitor is selected from one or a combination of diethylenetriamine, triethylenetetramine, tetraethylenepentamine.
4. The inhibited water-based foam drilling fluid system of claim 1 wherein said viscosifier is a water-transfer modified viscosifier formed from montmorillonite treated with a quaternary ammonium surfactant.
5. A suppressed aqueous foam drilling fluid system according to claim 2, characterized in that m = 6-8 and n = 1-2.
6. The method for preparing the inhibitory water-based foam drilling fluid system according to claim 1, wherein the preparation steps are as follows: firstly, adding a fluorocarbon foaming agent into a certain amount of water, slowly stirring until the fluorocarbon foaming agent is completely dissolved, and then sequentially and uniformly stirring an inhibitor, a foam stabilizer, a tackifier and bentonite.
7. The application of the inhibitory water-based foam drilling fluid system as claimed in claim 1, which is used in the field of oilfield drilling, and is suitable for the stratum with frequent upper stratum sand-shale interbedded, high hardness, high grindability and poor drillability and the low-pressure stratum with poor well wall stability.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211285736.9A CN117946642A (en) | 2022-10-20 | 2022-10-20 | Inhibitory water-based foam drilling fluid system |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211285736.9A CN117946642A (en) | 2022-10-20 | 2022-10-20 | Inhibitory water-based foam drilling fluid system |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN117946642A true CN117946642A (en) | 2024-04-30 |
Family
ID=90798765
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202211285736.9A Pending CN117946642A (en) | 2022-10-20 | 2022-10-20 | Inhibitory water-based foam drilling fluid system |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN117946642A (en) |
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2022
- 2022-10-20 CN CN202211285736.9A patent/CN117946642A/en active Pending
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