CN110219634B - Nano proppant high sand-liquid ratio volume fracturing method for deep shale gas - Google Patents
Nano proppant high sand-liquid ratio volume fracturing method for deep shale gas Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 39
- 238000010276 construction Methods 0.000 claims abstract description 32
- 239000004576 sand Substances 0.000 claims abstract description 32
- 239000003292 glue Substances 0.000 claims abstract description 20
- 238000002347 injection Methods 0.000 claims abstract description 19
- 239000007924 injection Substances 0.000 claims abstract description 19
- 239000002253 acid Substances 0.000 claims abstract description 13
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 13
- 238000011156 evaluation Methods 0.000 claims abstract description 12
- 238000006073 displacement reaction Methods 0.000 claims abstract description 11
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 10
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- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 3
- 238000005553 drilling Methods 0.000 description 3
- 229910052500 inorganic mineral Inorganic materials 0.000 description 3
- 239000011707 mineral Substances 0.000 description 3
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- 230000000704 physical effect Effects 0.000 description 3
- 230000035945 sensitivity Effects 0.000 description 3
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- 238000012360 testing method Methods 0.000 description 3
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
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- 238000005336 cracking Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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Abstract
The invention discloses a nano proppant high sand-liquid specific volume fracturing method for deep shale gas. The method comprises the following steps: (1) evaluation of key reservoir parameters (2) cluster position determination (3) fracture parameters and construction parameters are optimized (4) cluster perforation operation (5) acid pretreatment operation (6) low-viscosity slick water seam construction (7) nanometer proppant injection construction (8) high-viscosity glue seam construction and sand adding (9) displacement operation. According to the invention, the propping agent with the particle size of 200-2000 nm is selected and pumped under the condition of high sand ratio, so that the propping efficiency of the branch cracks and the micro cracks is improved, the static pressure in the main cracks is improved, and the purposes of improving the complexity of the deep shale gas fracturing cracks and effectively reconstructing the volume are achieved.
Description
Technical Field
The invention relates to the field of oil and gas exploitation, in particular to a nano proppant high sand-liquid specific volume fracturing method for deep shale gas.
Background
At present, deep shale gas fracturing enters a critical period, if initial production and yield decrease after fracturing do not meet commercial development requirements, investment can be greatly reduced, and a large amount of deep shale gas resources can not be effectively used for a long time.
From the technical point of view, most of the current deep shale gas fracturing technologies refer to the mode and parameters of the medium-shallow shale gas fracturing technology, and therefore, the adaptability and the effect of the fracturing technology need to be further improved.
Due to the increase of the depth, the friction resistance of a shaft is increased, the construction discharge capacity is reduced, the width of a seam is narrowed, and the construction sand-liquid ratio is reduced, so that the flow conductivity is reduced; the three-way stress increases, with a two-way horizontal stress difference increasing and the fracture complexity decreasing. And the flow conductivity of the crack is decreased quickly by increasing the minimum horizontal main stress. The difficulty of communication and extension of the horizontal layer reason seam/texture seam is increased due to the increase of the overlying stress, and the reconstruction volume of the crack is greatly reduced; with the increase of temperature and pressure, the shaping characteristic of the rock is enhanced, the fracture pressure and the extension stress of the rock are increased, and the difficulty of the diversion of the crack to form the branch crack is increased.
Chinese patent CN103527163A discloses a compact reservoir horizontal well volume fracturing process, which is characterized in that: and optimizing the fracture initiation sequence of the perforation clusters by taking the maximum induced stress difference as a target, and optimizing the interval of the perforation clusters to promote the fracture formation of complex fractures in the same fracturing section of the horizontal well.
The document 'breakthrough and understanding of the deep shale gas staged fracturing technology in south of the east of china' (natural gas industry, 2016, 6 months) proposes a new construction mode and a matching technology of 'pretreated acid + glue solution + slick water + glue solution' mixed fracturing based on analytical research on mechanical properties, ground stress characteristics, fracture characteristics and fracture morphology characteristics of deep rock. The field application effect shows that: obtaining the unimpeded flow of shale gas by 10.5 multiplied by 10 after the Longmaxi group pressure of the Dingye 2HF Reguland System4m3And d, obtaining geological breakthrough; obtaining the unimpeded shale gas flow rate of 10.5 multiplied by 10 after the golden page 1HF is pressed by a Temple tumidinodactyla tumidinoda4m3And/d, is expected to be a commercial breakthrough.
The above references are not sufficiently concerned with the stimulation of microcracks.
Therefore, the difficulties cause the adaptability of the conventional shale gas fracturing technology to be poor and the fracturing effect to be undesirable. There is a need to develop a new deep shale gas pressure fracturing technology to solve the above problems.
Disclosure of Invention
In order to solve the problems of low complexity and incomplete crack filling in deep shale gas volume fracturing, the invention provides a nano proppant high sand-liquid ratio volume fracturing method for deep shale gas, which is characterized in that a proppant with the particle size of 200-2000 nm is selected and pumped under the condition of high sand ratio, so that the supporting efficiency of branch cracks and micro cracks is improved, the static pressure in a main crack is improved, and the purposes of improving the complexity of deep shale gas fracturing cracks and effectively modifying the volume are achieved.
The invention aims to provide a nano proppant high sand-liquid specific volume fracturing method for deep shale gas.
The method comprises the following steps:
(1) evaluation of key reservoir parameters
(2) Segment cluster position determination
(3) Optimizing crack parameters and construction parameters
(4) Cluster perforation operation
(5) Acid pretreatment operation
(6) Low-viscosity slick water seam construction
(7) Nano-scale proppant injection construction
(8) High viscosity glue solution for making seam and adding sand
(9) And (5) replacing operation.
Preferably:
and (4) perforating each section of the holes in 1-2 clusters, wherein the hole density is 16-20 holes/meter, the length of each cluster of the holes is 1-2m, and the aperture is more than 9.5 mm.
Step (5), the discharge capacity is 1-2m3Min, liquid amount of 10-20m3The displacement of the acid is 4-6m3/min。
And (6) taking the liquid amount required when the seam length reaches 65-75% of the expected seam length designed in the step (3) as the volume of the slick water in the stage, and injecting the liquid amount by taking 65-75% of the optimized discharge amount in the step (3).
And (6) the viscosity range of the low-viscosity slick water is 3-5 mPa.s.
Step (7), the particle size range of the propping agent is 200-2000 nm, the starting sand-liquid ratio is 10 percent,
a continuous sand adding mode is adopted,
the sand-liquid ratio is 10% -15% -20% -25% -30% -35% -40% -45% -50% -55% -60%.
And (7) when the stratum needs to be plugged for multiple times and turned, the sand adding procedure is divided into two sand adding procedures which are repeatedly executed, and the two sand adding procedures are recommended to complete the injection of the total amount of the proppant according to the proportion of 3: 7-4: 6.
Step (8), injecting high-viscosity glue, and taking the maximum designed discharge capacity as the discharge capacity; adopting a long slug continuous construction mode, and adopting 40-70 mesh ceramic proppant; the sand-liquid ratio is 10% -13% -16% -0% -16% -19% -22% -25%.
And (8) the viscosity of the high-viscosity glue solution is greater than or equal to 30 mPa.s.
The invention can adopt the following technical scheme:
the specific process and steps are as follows:
(1) evaluation of key reservoir parameters
The method comprises lithology and mineral composition and sensitivity evaluation, physical properties, rock mechanics and elastoplastic deformation characteristics, three-dimensional ground stress, bedding seam/texture seam and natural fracture characteristics and the like, and can be comprehensively carried out by using methods such as well logging, core experiments and the like.
(2) Segment cluster position determination
And (3) evaluating the geological dessert and the engineering dessert on the basis of the step (1), and preferentially determining the geological dessert and the engineering dessert positions as segment cluster candidate positions. And calculating the comprehensive dessert indexes according to an equal weight method, and finally determining the final cluster perforation position according to the sequencing result.
(3) Optimizing crack parameters and construction parameters
And (2) establishing a geological model based on the evaluation result of the step (1), setting different seam lengths, seam conductivity, seam intervals and seam length layouts by applying commercial software ECLIPSE for shale gas fracturing yield prediction, and determining a fracture parameter combination with relatively highest yield after fracturing according to an orthogonal design method. On the basis, different fracturing construction parameter combinations are simulated by applying commercial software MEYER for shale gas fracturing fracture propagation simulation.
(4) Cluster perforation operation
On the basis of the step (2), perforating operation is carried out by adopting a conventional bridge plug perforating combination technology, each section of perforation is generally 1-2 clusters, the hole density is generally 16 holes/meter, the length of each cluster of perforation is generally 1m, and the hole diameter is generally more than 9.5 mm.
(5) Acid pretreatment operation
The diluted hydrochloric acid or rare earth acid is generally adopted for injection, and the discharge capacity is generally 1-2m3Min, liquid amount of 10-20m3The displacement of the acid is generally 4-6m3/min。
(6) Low-viscosity slick water seam construction
According to the thought (1), based on the MEYER simulation result, the liquid amount required when the slit length reaches about 70% of the design expected slit length in the step (3) is taken as the slickwater volume in the stage, and the displacement is taken as 70% of the optimized displacement in the step (3) for injection.
(7) Nano-scale proppant injection construction
After the step (6) is finished, injecting 2000-grade propping agent with the particle size of 200-grade sand-adding agent immediately, starting the sand-liquid ratio to be 10 percent, and adopting a continuous sand-adding mode, wherein the sand-adding procedure is generally 10-15-20-25-30-35-40-45-50-55-60 percent. And (4) adjusting the sand adding time of each section according to the corresponding support agent amount designed in the step (3).
The use of the nano propping agent improves the filling of the branch seams and the micro seams on one hand, and plays a role in temporarily blocking and turning on the other hand, the filling of the branch seams and the micro seams improves the static pressure in the main seams, realizes the turning of the main seams and the cracking opening of more branch seams, and further improves the complexity of the seams. Therefore, when the stratum needs to be plugged for a plurality of times and turned, the sand adding procedure can be divided into two sand adding procedures which are repeatedly executed, and the two sand adding procedures are recommended to complete the injection of the total amount of the proppant according to the proportion of 4: 6.
(8) High viscosity glue solution for making seam and adding sand
And (4) after the step (6) is finished, injecting high-viscosity glue solution based on the simulation result of the step (3), and taking the highest discharge capacity of the design. Considering that the joint forming and sand adding are carried out synchronously at the stage, the joint forming function is also realized at the early stage low sand-liquid ratio section. A long-section plug continuous construction mode can be adopted, and 40-70 mesh ceramsite proppant is adopted. The sand-liquid ratio can be 10% -13% -16% -0% (slug) -16% -19% -22% -25%. And (4) adjusting each construction time according to the supporting dosage of 40-70 meshes designed in the step (3).
(9) Replacement work
At this stage, the displacement is preferably 120-130% of the wellbore volumeEarly stage 20-30m3The high-viscosity glue solution is used as a standard to increase the cleaning effect on the settled sand of the horizontal shaft and ensure the smooth operation of the subsequent lower bridge plug operation. And replacing with low-viscosity slick water until the designed liquid amount is filled.
(10) Other drilling and plugging, flowback, test and production, etc. are performed according to the conventional flow, which is not redundant here.
The traditional fracturing only focuses on main cracks and at most branch cracks, neglects the contribution of micro cracks to production increase, along with the technical progress, the micro cracks are gradually emphasized, and secondly, the research on the flow conductivity of the nano proppant shows that the nano proppant has better long-term flow conductivity, thereby eliminating the worry of people on the supporting effect.
The difference of the nano proppant sand adding and the traditional proppant in the technology is that the nano proppant has small particle size and is convenient to carry, so that a high sand ratio and continuous slug adding mode is adopted, the continuous sand adding mode can be adopted for the conventional proppant under the condition of low construction difficulty, but the construction difficulty of deep shale is high, the slug sand adding is generally adopted, and in addition, the sand adding concentration of the conventional proppant is less than that of the nano proppant.
The creativity of the invention is that the application of the new type of propping agent is realized, namely the combination of the nano propping agent and the deep shale fracturing, and the problems of difficult sand addition, narrow crack, limited reconstruction volume, insufficient support and the like of the deep shale are solved; on the other hand, a specific nano proppant introduction method, a sand adding mode, sand concentration and other key parameters are provided, which are not related to the prior art.
The invention has the following technical characteristics and excellent effects:
the invention has novel thought, clear method system and steps, is practical and feasible, and provides a novel nano proppant high sand-liquid ratio volume fracturing technology aiming at the commercial development of deep shale, thereby improving the complexity of gas-fracturing fracture of deep complex shale, improving the filling efficiency of branch cracks and micro cracks, improving the effective reconstruction volume of deep complex shale gas, and improving the yield-increasing and stable-yield effects after the fracturing.
Detailed Description
The present invention will be further described with reference to the following examples.
Example 1:
a well for a certain deep layer of shale gas A,
(1) evaluation of key reservoir parameters
The method comprises the following steps of lithology, mineral composition and sensitivity evaluation, physical properties, rock mechanics and elastic-plastic deformation characteristics, three-dimensional ground stress, bedding seams/texture seams and natural fracture characteristics.
(2) Segment cluster position determination
And (3) evaluating the geological dessert and the engineering dessert on the basis of the step (1), and preferentially determining the geological dessert and the engineering dessert positions as segment cluster candidate positions.
(3) Optimizing crack parameters and construction parameters
And (2) establishing a geological model based on the evaluation result of the step (1), setting different seam lengths, seam conductivity, seam intervals and seam length layouts by applying commercial software ECLIPSE for shale gas fracturing yield prediction, determining a fracture parameter combination with relatively highest yield after fracturing according to an orthogonal design method, and adopting an equal seam length seam distribution mode for the well.
(4) Cluster perforation operation
And (3) performing perforating operation by adopting a conventional bridge plug perforating combination technology on the basis of the step (2).
(5) Acid pretreatment operation
The well is filled with dilute hydrochloric acid with a discharge capacity of 1.5m3Min, liquid volume 20m3Displacement of displacing acid 5m3/min。
(6) Low-viscosity slick water seam construction
According to the idea (1), based on MEYER simulation results, the liquid amount of 8600m required for the slit length to reach 70% of the design expected slit length in the step (3) is taken3Taking 70% (5 m) of the optimized displacement in the step (3) as the volume of the slick water in the stage3Min) injection; the viscosity of the low-viscosity slickwater was 3 mpa.s.
(7) Nano-scale proppant injection construction
After the step (6) is finished, injecting 2000-nanometer proppant with the grain diameter of 200-,
the sand adding procedure is 10% -15% -20% -25% -30% -35% -40% -45% -50% -55%, and the total injection amount is 730m3。
(8) High viscosity glue solution for making seam and adding sand
After the step (6) is finished, based on the simulation result of the step (3), injecting high-viscosity glue solution, and taking the designed maximum discharge capacity of 14m as the discharge capacity3And/min, adopting a long slug continuous construction mode and adopting 40-70 mesh ceramsite proppant. The sand-liquid ratio can be 10% -13% -16% -0% (slug) -16% -19% -22% -25%; the viscosity of the high-viscosity glue solution is 30 mPa.s.
(9) Replacement work
Injection of 30m3Replacing the high-viscosity glue solution.
(10) Other drilling and plugging, flowback, test and production, etc. are performed according to the conventional flow, which is not redundant here.
The well adopts a new deep shale gas nano proppant high sand-liquid specific volume fracturing technology to complete fracturing operation, and improves the fracturing transformation effect by adopting a new proppant and optimizing an injection mode and a program, and the daily produced gas of the well after the well is fractured is 82000m3And compared with other exploratory wells in the same block, the yield is improved by over 51 percent.
Example 2:
a certain deep shale gas B well:
(1) evaluation of key reservoir parameters
The method comprises the following steps of lithology, mineral composition and sensitivity evaluation, physical properties, rock mechanics and elastic-plastic deformation characteristics, three-dimensional ground stress, bedding seams/texture seams and natural fracture characteristics.
(2) Segment cluster position determination
And (3) evaluating the geological dessert and the engineering dessert on the basis of the step (1), and preferentially determining the geological dessert and the engineering dessert positions as segment cluster candidate positions.
(3) Optimizing crack parameters and construction parameters
And (2) establishing a geological model based on the evaluation result of the step (1), setting different seam lengths, seam conductivity, seam intervals and seam length layouts by applying commercial software ECLIPSE for shale gas fracturing yield prediction, determining a fracture parameter combination with relatively highest yield after fracturing according to an orthogonal design method, and adopting a W-shaped seam arrangement mode for the well.
(4) Cluster perforation operation
And (3) performing perforating operation by adopting a conventional bridge plug perforating combination technology on the basis of the step (2).
(5) Acid pretreatment operation
The well is filled with dilute hydrochloric acid with a discharge capacity of 1.5m3Min, liquid volume 15m3Displacement of displacing acid 4.5m3/min。
(6) Low-viscosity slick water seam construction
According to the idea (1), based on MEYER simulation results, the liquid amount 11000m needed when the slit length reaches about 70% of the design expected slit length in the step (3) is taken3Taking 70% (5 m) of the optimized displacement in the step (3) as the volume of the slick water in the stage3/min) injection. The viscosity of the low-viscosity slickwater is 5 mPa.s.
(7) Nano-scale proppant injection construction
After the step (6) is finished, injecting 2000-nanometer proppant with the grain diameter of 200-,
the sand adding procedure is 10% -15% -20% -25% -30% -35% -40% -45% -50% -55%, and the total injection amount is 960m3。
(8) High viscosity glue solution for making seam and adding sand
After the step (6) is finished, based on the simulation result of the step (3), injecting high-viscosity glue solution, and taking the designed maximum discharge capacity of 15m as the discharge capacity3And/min, adopting a long slug continuous construction mode and adopting 40-70 mesh ceramsite proppant. The sand-liquid ratio can be 10% -13% -16% -0% (slug) -16% -19% -22% -25%. The viscosity of the high viscosity glue was 45 cp.
(9) Replacement work
Injection of 30m3Replacing the high-viscosity glue solution.
(10) Other drilling and plugging, flowback, test and production, etc. are performed according to the conventional flow, which is not redundant here.
The well adopts a novel deep shale gas nano proppant with high sand-to-liquid ratioThe new volume fracturing technology completes fracturing operation, improves the fracturing transformation effect by adopting new propping agent and optimizing injection mode and program, and produces gas of 95000m in the future after well fracturing3And the yield is improved by more than 65% compared with other exploratory wells in the same block.
Comparative example:
the maximum vertical depth of the shale gas X well is 4180m, the conventional design method is adopted to carry out fracturing construction transformation, and the daily gas production after fracturing is 52000m3The yield is lower, the decline is faster, and the modification effect is obviously lower than that of the shale gas well modified by implementing the new technology.
Claims (6)
1. A nano proppant high sand-to-liquid volume fracturing method for deep shale gas is characterized by comprising the following steps:
(1) evaluation of key reservoir parameters
(2) Segment cluster position determination
(3) Optimizing crack parameters and construction parameters
(4) Cluster perforation operation
(5) Acid pretreatment operation
(6) Low-viscosity slick water seam construction
The viscosity range of the low-viscosity slickwater is 3-5 mPa.s;
(7) nano-scale proppant injection construction
The particle size range of the propping agent is 200-2000 nm, the starting sand-liquid ratio is 10 percent,
a continuous sand adding mode is adopted,
the sand-liquid ratio is 10% -15% -20% -25% -30% -35% -40% -45% -50% -55% -60%;
(8) high viscosity glue solution for making seam and adding sand
The viscosity of the high-viscosity glue solution is more than or equal to 30 mPa.s;
(9) and (5) replacing operation.
2. The nano proppant high sand-liquid specific volume fracturing method for deep shale gas as set forth in claim 1, characterized in that:
and (4) perforating each section of the holes in 1-2 clusters, wherein the hole density is 16-20 holes/meter, the length of each cluster of the holes is 1-2m, and the aperture is more than 9.5 mm.
3. The nano proppant high sand-liquid specific volume fracturing method for deep shale gas as set forth in claim 1, characterized in that:
step (5), the discharge capacity is 1-2m3Min, liquid amount of 10-20m3The displacement of the acid is 4-6m3/min。
4. The nano proppant high sand-liquid specific volume fracturing method for deep shale gas as set forth in claim 1, characterized in that:
and (6) taking the liquid amount required when the seam length reaches 65-75% of the expected seam length designed in the step (3) as the volume of the slick water in the stage, and injecting the liquid amount by taking 65-70% of the optimized discharge amount in the step (3).
5. The nano proppant high sand-liquid specific volume fracturing method for deep shale gas as set forth in claim 1, characterized in that:
and (7) when the stratum needs to be plugged for multiple times and turned, the sand adding procedure is divided into two sand adding procedures which are repeatedly executed, and the two sand adding procedures complete the injection of the total amount of the proppant according to the proportion of 3: 7-4: 6.
6. The nano proppant high sand-liquid specific volume fracturing method for deep shale gas as set forth in claim 1, characterized in that:
step (8), injecting high-viscosity glue, and taking the maximum designed discharge capacity as the discharge capacity; adopting a long slug continuous construction mode, and adopting 40-70 mesh ceramic proppant; the sand-liquid ratio is 10% -13% -16% -0% -16% -19% -22% -25%.
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| CN113530513B (en) * | 2020-04-22 | 2023-02-28 | 中国石油化工股份有限公司 | Fracturing method for graded support of proppants with different particle sizes in multi-scale fracture |
| CN114427417B (en) * | 2020-09-24 | 2024-07-05 | 中国石油化工股份有限公司 | Multilayer reservoir fracturing method with large stress difference and application |
| CN114427424A (en) * | 2020-09-28 | 2022-05-03 | 中国石油化工股份有限公司 | Deep oil and gas reservoir directional fracturing method and application |
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| CN105317415B (en) * | 2014-06-23 | 2018-10-16 | 中国石油集团渤海钻探工程有限公司 | Stitch net fracturing technology method |
| CN105275446B (en) * | 2014-06-30 | 2018-03-30 | 中国石油化工股份有限公司 | A kind of volume fracturing remodeling method |
| CN104564007B (en) * | 2014-12-30 | 2017-06-23 | 中国石油天然气股份有限公司 | Vertical well fracture network fracturing process for non-fractured compact sand-shale reservoir |
| AU2015384216B2 (en) * | 2015-02-24 | 2018-08-09 | Halliburton Energy Services, Inc. | System and method for hydraulic fracturing with nanoparticles |
| US20160355727A1 (en) * | 2015-06-05 | 2016-12-08 | The University Of Kansas | Nano-proppants for fracture conductivity |
| US20180298272A1 (en) * | 2015-10-05 | 2018-10-18 | Schlumberger Technology Corporation | Polymeric and elastomeric proppant placement in hydraulic fracture network |
| CN106907137B (en) * | 2015-12-23 | 2019-01-01 | 中国石油化工股份有限公司 | A kind of method of the effective water conservancy diversion in shale oil reservoir volume fracturing crack |
| CN107545088B (en) * | 2016-06-29 | 2020-06-02 | 中国石油化工股份有限公司 | Normal-pressure shale gas horizontal well volume fracturing method |
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