CN114482971A - Unconventional reservoir fracturing modification proppant optimization method and application - Google Patents
Unconventional reservoir fracturing modification proppant optimization method and application Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 35
- 238000012986 modification Methods 0.000 title claims abstract description 25
- 230000004048 modification Effects 0.000 title claims abstract description 25
- 238000005457 optimization Methods 0.000 title claims abstract description 23
- 238000004519 manufacturing process Methods 0.000 claims abstract description 16
- 238000012360 testing method Methods 0.000 claims abstract description 13
- 239000002245 particle Substances 0.000 claims abstract description 11
- 238000010276 construction Methods 0.000 claims abstract description 10
- 230000008859 change Effects 0.000 claims abstract description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 27
- 238000004088 simulation Methods 0.000 claims description 20
- 239000004576 sand Substances 0.000 claims description 18
- 238000011160 research Methods 0.000 claims description 13
- 239000006004 Quartz sand Substances 0.000 claims description 9
- 239000011435 rock Substances 0.000 claims description 9
- 239000003795 chemical substances by application Substances 0.000 claims description 6
- 230000015572 biosynthetic process Effects 0.000 claims description 4
- 238000004364 calculation method Methods 0.000 claims description 3
- 238000002474 experimental method Methods 0.000 claims description 3
- 238000000520 microinjection Methods 0.000 claims description 2
- 230000035945 sensitivity Effects 0.000 claims description 2
- 239000003607 modifier Substances 0.000 claims 4
- 238000010187 selection method Methods 0.000 claims 1
- 230000007774 longterm Effects 0.000 abstract description 4
- 230000000694 effects Effects 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 13
- 239000007789 gas Substances 0.000 description 6
- 238000004458 analytical method Methods 0.000 description 3
- 238000013461 design Methods 0.000 description 3
- 239000011295 pitch Substances 0.000 description 3
- 238000013211 curve analysis Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 230000009466 transformation Effects 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000008161 low-grade oil Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 239000003079 shale oil Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
Abstract
The invention provides an unconventional reservoir fracturing modification proppant optimization method and application. The preferred method comprises: the method comprises the steps of obtaining the requirement of full-use diversion capacity of reserves under different fracture intervals by using oil reservoir numerical simulation software, obtaining a stratum closed stress value by using an actual well fracturing construction curve, obtaining an effective closed stress change value by combining an actual fracturing well production curve, carrying out a long-term diversion capacity test under a simulated actual stress condition to obtain a fracture diversion capacity value under different proppant combination conditions, and finally obtaining parameters such as proppant types, particle sizes, addition and the like which can meet the full-use requirement of the oil reservoir by using fracturing software. The optimization method can better guide the optimization of the propping agent in different modification modes of the unconventional reservoir and improve the fracturing modification effect of the unconventional reservoir.
Description
Technical Field
The invention relates to the field of yield increasing transformation of oil and gas wells, in particular to a method for optimizing proppant for unconventional reservoir fracturing transformation and application.
Background
Unconventional reservoirs such as compact oil, shale oil and gas and the like become key and hot spots of oil and gas exploration and development in China, and a horizontal well combined with volume fracturing modification is a key for realizing effective utilization of low-grade oil and gas resources. The mobility, the starting fracturing gradient, the fracture spacing and the production mode of different types of unconventional reservoirs are greatly different, so that the requirement difference of different reservoirs on fracturing flow conductivity is large, and the key for determining the modification effect and the cost is to optimize the type and the using amount of the proppant suitable for the reservoirs. Currently, the optimization of low-permeability reservoir proppant at home and abroad is mainly optimized based on a proppant index method, the dosage of the proppant is optimized according to the physical properties of the reservoir (Jianting science and the like, fracturing optimization design method research of low-permeability reservoir based on proppant index, oil drilling and production process 2008, 30(3)), the research on the problem of fracturing and improving the proppant of the unconventional reservoir mainly aims to discuss the feasibility of quartz sand for replacing ceramsite and optimize the economic flow conductivity suitable for the reservoir, to reduce the fracturing cost (Yanglifeng, etc., economic adaptability of quartz sand for shale gas reservoir fracturing, natural gas industry, 2018,38(5)), but the current research is mainly suitable for proppant optimization of vertical well fracturing, for the horizontal well, the optimization difficulty of the proppant is high due to the fact that parameters influencing the flow conductivity requirement of a reservoir include reservoir mobility, starting fracturing gradient, fracture interval, effective stress change and the like. Therefore, it is highly desirable to establish a set of preferred methods for modifying proppants suitable for unconventional reservoir fracturing.
Disclosure of Invention
In order to solve the above problems, it is an object of the present invention to provide an unconventional reservoir fracturing modification proppant optimization method. The method has reliable theory and simple design.
It is another object of the present invention to provide the use of the preferred method of unconventional reservoir fracturing reformation proppant.
To achieve the above objects, in one aspect, the present invention provides a preferred method for unconventional reservoir fracture modification of proppant, comprising the steps of: step 1: collecting actual reservoir rock cores of a research block, developing an indoor experiment to obtain key parameters of reservoir mobility, starting fracturing gradient, stress sensitivity and the like of the research block, and providing parameters for numerical simulation of an oil reservoir; step 2: on the basis of the parameters obtained in the step 1, the fracture conductivity required by the total utilization of the reservoir volume of the modified well can be realized under the condition of simulating different fracture intervals by adopting oil reservoir numerical simulation software, and meanwhile, according to the simulation result, a fracture conductivity requirement chart under the conditions of comprehensively considering reservoir mobility, starting pressure gradient and fracture intervals is established to guide the optimization of the fracture conductivity under different types of reservoirs, different modification processes and modification modes; and step 3: acquiring construction data of a fracturing modification well implemented in a research block, analyzing and acquiring effective closed stress parameters of a reservoir stratum of the research block through fracturing construction data, and acquiring a fracture effective closed stress change curve during the production period of a fracturing well of a target block by using production data of the well; and 4, step 4: taking the effective closure stress parameter of the step 3 as an experimental condition, carrying out the test of the conductivity of the support fracture under different types, particle sizes and sanding concentration under the simulation of actual production characteristics, and obtaining the conductivity of the support fracture under the combination condition of different proppant types; and 5: and (3) carrying out fracture simulation by using hydraulic fracturing optimization design software, determining the type, the particle size and the single-fracture sand adding amount parameters of the propping agent required for realizing the fracture conductivity required by the step 2, and guiding the optimization of the unconventional reservoir fracturing modification propping agent.
According to some embodiments of the invention, the actual reservoir core in step 1 is selected from a drill-cored rock sample or a flush rock sample at the same level.
According to some embodiments of the invention, the rock sample has a diameter of 2.5cm and a length of 5 cm.
According to some embodiments of the present invention, the reservoir numerical simulation software in step 2 may be CMG software of canadian computer software simulation or Eclipse software of schlumberger.
According to some embodiments of the present invention, the simulation range of the different crack spacing in step 2 is 5-30m, and the spacing between two adjacent cracks is 5 m. Specifically, the different crack pitches can be set by taking the crack pitch designed in the earlier stage of the research block as a reference and combining the current mainstream crack pitch at home and abroad.
According to some embodiments of the present invention, the construction data of the well subjected to fracture modification in step 3 is selected from data of a micro-injection test of the well, data of a small-scale fracture test or data after large-scale fracture construction, and the closing stress parameter of the reservoir is obtained by a method such as G function analysis or log-log curve analysis.
According to some embodiments of the present invention, the effective closure stress calculation formula in step 3 is as follows:
in the formula: sigmae(t) is the effective closure stress at any time in MPa; sigmacInitial fracture closure stress in MPa; alpha is a biot coefficient; ν is the poisson ratio; piIs the original formation pressure; p (t) is the formation pressure at any time; the unit is MPa; pf(t) is the bottom hole flowing pressure at any time, and the unit is MPa.
According to some embodiments of the present invention, the different proppant types of step 4 are selected from any two combinations of ceramsite, quartz sand and coated sand.
According to some embodiments of the invention, the particle size of the proppant is selected from any one or a combination of two or more of 20 mesh to 40 mesh, 30 mesh to 50 mesh, 40 mesh to 70 mesh, 70 mesh to 140 mesh.
According to some embodiments of the invention, the proppant is spread in step 4The sand concentration is 1-10kg/m2。
According to some embodiments of the present invention, the hydraulic fracture optimization design software of step 5 is the StimPlan software of Pinnacle corporation FracPT or NSI corporation.
According to some embodiments of the present invention, in step 5, the fracture simulation is performed by setting proppant parameters according to the experimental data obtained in step 4.
In another aspect, the invention also provides the application of the preferred method for modifying the proppant in the unconventional reservoir fracturing in unconventional oil and gas wells.
The invention has the beneficial effects that:
the method optimizes key parameters such as the type and the dosage of the propping agent aiming at different types of reservoirs and different fracturing fracture parameters. The method is reliable in theory and simple in design, comprehensively considers the requirements of different modification modes of different types of reservoirs on the flow conductivity and the flow conductivity provided by the proppant in the horizontal well volume fracturing mode, and finally preferably selects the parameters such as the type and the using amount of the proppant suitable for the reservoirs. The optimization method has wide application prospect for guiding the optimization of unconventional reservoir proppant.
Drawings
FIG. 1 is a chart of the flow conductivity requirement of Mar lake compact oil in example 1 of the present invention;
FIG. 2 is a graph of single well production for example 1 of the present invention;
FIG. 3 is a graph showing the effective closing stress variation in the production process of example 1 of the present invention;
FIG. 4 is a long-term conductivity test chart of the simulation production history in example 1 of the present invention;
FIG. 5 is a graph of conductivity for different proppant types, particle sizes and sanding concentrations for example 1 of the present invention;
FIG. 6 is a cross-sectional view of the simulation of sand-scale fracture sanding of different propping types according to example 1 of the present invention.
Detailed Description
The technical solutions of the present invention will be described in detail below in order to clearly understand the technical features, objects, and advantages of the present invention, but the present invention is not limited to the practical scope of the present invention.
Example 1
The embodiment provides a preferable method for unconventional reservoir fracturing modification proppant, which comprises the following specific steps:
step 1: firstly, selecting stratum cores of compact oil blocks of Marx, Mary and the like of Mary conglomerate in Xinjiang, cutting the stratum cores into rock pillars with the diameter of 2.5cm and the length of 4-5cm, then carrying out a core displacement experiment to obtain permeability parameters and starting pressure gradient parameters of the core of the reservoir, and calculating by combining crude oil viscosity parameters under the reservoir condition to obtain fluidity parameters under the reservoir condition, wherein key parameters of the reservoir are detailed in Table 1.
TABLE 1 Key parameters of reservoir
The fluidity of the Marx block is 1.01 mD/mPa.s, the starting fracturing gradient is 0.014MPa/m, the fluidity of the Mary block is 0.41 mD/mPa.s, the starting fracturing gradient is 0.14MPa/m, the fluidity of the Fennan Z block reservoir is 0.06 mD/mPa.s, and the starting fracturing gradient is 0.45 MPa/m.
And 2, step: and (3) carrying out flow conductivity requirement simulation for realizing full reserve utilization under the conditions of different blocks and different crack distances of the Mary lake conglomerate compact oil in Xinjiang by adopting CMG oil reservoir numerical simulation software on the basis of the reservoir parameters obtained in the step (1).
The mobility of the Marx block is high, the starting fracturing gradient is low, full reserve utilization can be realized at a gap of 30m, the crack conductivity requirement is 20D-cm at a gap of 30m, the crack conductivity requirement is 15D-cm at a gap of 20m, and the crack conductivity requirement is 8D-cm at a gap of 10 m;
the fluidity of the MaY block is low, the starting pressure gradient is high, the full reserve utilization can be realized only at the gap of 20m, the crack conductivity requirement is 20D-cm at the gap of 20m, the crack conductivity requirement is 10D-cm at the gap of 15m, and the conductivity requirement is 5D-cm at the gap of 10 m; the flow conductivity requirement of the 5m seam interval is 2D cm;
the Z-shaped block in Fengnan has low fluidity and high starting pressure gradient, the reserve can be fully used only at the gap of 15m, the crack diversion capacity requirement at the gap of 15m is 15D cm, the crack diversion capacity requirement at the gap of 10m is 8D cm, and the diversion capacity requirement at the gap of 5m is 1D cm;
and (3) establishing a flow conductivity requirement chart of the Mar lake compact oil block according to a flow conductivity requirement result of realizing seam control of reservoirs with different blocks, different fluidity and starting pressure gradient at different seam intervals obtained through simulation, as shown in figure 1. The flow conductivity requirements of the cracks under different fluidity and gap spacing conditions can be obtained through the plate shown in FIG. 1.
And step 3: and collecting construction data of the fracturing modified wells of the Marhu compact oil block, and analyzing and obtaining reservoir closed stress parameters of the research block through a fracturing curve. Wherein: the method comprises the steps of obtaining the closure stress of a Marx block to be about 72MPa, obtaining the closure stress of the Mary block to be shallow through a small-sized test fracturing analysis method by G function analysis, double logarithmic curve analysis and other methods, obtaining the closure stress of the Mary block to be about 55MPa, obtaining the closure stress of a Fennan Z block to be shallow, and obtaining the closure stress of the Marx block to be about 50 MPa.
On the basis of obtaining the initial closing stress of the fractured well, collecting production information of the fractured well, as shown in fig. 2, obtaining the change relationship of the yield and the pressure along with the time from the production information, and calculating an effective closing stress change curve of the fracture during the production through a formula (1), as shown in fig. 3.
And 4, step 4: taking the obtained parameters in the step 3 as experimental conditions, carrying out the conductivity test of the supporting fractures under different types, particle sizes and sand laying concentrations under the simulation of actual production characteristics, and obtaining the conductivity of the supporting fractures under different proppant combination conditions;
the method mainly tests three types of ceramsite, quartz sand, precoated sand and the like; 70/140 mesh, 40/70 mesh, 30/50 mesh, 20/40 mesh and other particle sizes; 1kg/m2、2.5kg/m2、5kg/m2、7.5kg/m2、10kg/m2And (3) testing the long-term conductivity (more than 120 hours) under the conditions of different sand laying concentrations, wherein the typical long-term conductivity test curve is shown in figure 4The conductivity in three stages of gradual pressurization, stable testing and cyclic stress loading is tested, and the tested conductivity data are summarized, and the result is shown in fig. 5, and the experimental parameters are used as the basis of the minimum sand laying concentration required by the fracture simulation optimization proppant.
And 5: and (3) developing fracture simulation by using FracPT hydraulic fracturing optimization design software, and determining the proppant type, the particle size and the single-fracture sand adding amount parameters required for realizing the fracture conductivity required by the step (2).
FracPT hydraulic fracturing optimization design software is used for establishing a fractured well fracture simulation geology and geomechanics model, and then fracture simulation under different types of propping agents and sand adding scales is carried out, as shown in figure 6. The optimal proppant combination and sand addition scale was determined from fig. 6. The simulation calculation results in:
the reservoir of the Marx block is buried deeply, the combination of 40/70-mesh ceramsite and 20/40-mesh ceramsite is preferably selected when the gap distance is 30m, and the single-gap sand adding amount is 35m3(ii) a The preferred 40/70 mesh ceramsite proppant has the gap distance of 20m, and the single-gap sand adding amount is 30m3(ii) a The preferred quartz sand proppant with 40/70 meshes is arranged at the gap distance of 15m, and the sand adding amount of a single gap is 35m3。
The Mary blocks and Fengnan Z blocks are buried shallowly, the combination of 40/70-mesh quartz sand and 20/40-mesh quartz sand is preferred when the gap distance is 20m, and the sand adding amount of a single gap is 30m3(ii) a The quartz sand with the gap spacing of 10m, preferably 70/140 meshes and 40/70 meshes is combined, and the sand adding amount of a single gap is 25m3。
Claims (13)
1. A method for optimizing unconventional reservoir fracturing modification proppant is characterized by comprising the following steps:
step 1: collecting actual reservoir rock cores of the research block, and obtaining parameters of the reservoir of the research block: reservoir mobility, start-up fracture gradient, and stress sensitivity;
step 2: on the basis of the parameters obtained in the step 1, simulating the fracture conductivity required by full exploitation of the reservoir capacity of the modified well under the condition of different fracture intervals by adopting oil reservoir numerical simulation software, and establishing a fracture conductivity requirement chart comprehensively considering reservoir mobility, starting pressure gradient and fracture intervals;
and 3, step 3: acquiring construction data of a fracturing modification well implemented in a research block, analyzing and acquiring effective closed stress parameters of a reservoir stratum of the research block through fracturing construction data, and acquiring a fracture effective closed stress change curve during the production period of a fracturing well of a target block by using production data of the well;
and 4, step 4: taking the obtained effective closure stress parameter in the step 3 as an experimental condition, developing an experiment for simulating the flow conductivity of the lower support fracture in actual production under different proppant types, particle sizes and sanding concentrations, and obtaining the flow conductivity of the lower support fracture under different proppant type combination conditions;
and 5: and (3) carrying out fracture simulation by using hydraulic fracturing optimization design software, and determining the type, the particle size and the single-fracture sand adding amount parameters of the propping agent required by the fracture conductivity required by the step 2 so as to optimize the fracturing modification propping agent of the unconventional reservoir.
2. The unconventional reservoir fracturing modification proppant preference method of claim 1, wherein the actual reservoir core in step 1 is selected from a drill-cored rock sample or a zonal outcrop rock sample.
3. The preferred method of unconventional reservoir fracturing modifier proppant as set forth in claim 2, wherein the rock sample is 2.5cm in diameter and 5cm in length.
4. The preferred method of unconventional reservoir fracturing modifier proppant of any one of claims 1-3, wherein the reservoir numerical simulation software in step 2 is selected from CMG or Eclipse.
5. The unconventional reservoir fracturing modification proppant optimization method as set forth in claim 1, wherein the simulation range of the different fracture spacing in step 2 is 5-30m, and the spacing between two adjacent fractures is 5 m.
6. The preferred method of unconventional reservoir fracture modification proppant of claim 1, wherein the data of step 3 for the well construction that has been performed is selected from the group consisting of data from micro-injection testing of the well, data from fracturing tests, and data after fracturing construction.
7. The unconventional reservoir fracturing modification proppant optimization method of claim 1, wherein the effective closure stress calculation formula in step 3 is as in formula (1):
in the formula: sigmae(t) is the effective closure stress at any time in MPa; sigmacInitial fracture closure stress in MPa; alpha is a biot coefficient; ν is the poisson ratio; piIs the original formation pressure; p (t) is the formation pressure at any time; the unit is MPa; pf(t) is the bottom hole flowing pressure at any time, and the unit is MPa.
8. The preferred method of unconventional reservoir fracturing modifier proppant of claim 1, wherein the different proppant types of step 4 are selected from the group consisting of ceramsite, quartz sand, and coated sand.
9. The preferred method for modifying the fracturing of unconventional reservoir with proppant as set forth in any one of claims 1 to 8, wherein the particle size of proppant in step 4 is selected from any one or a combination of two or more of 20 mesh to 40 mesh, 30 mesh to 50 mesh, 40 mesh to 70 mesh, and 70 mesh to 140 mesh.
10. The unconventional reservoir fracturing modification proppant preference method of claim 1, wherein the sand concentration of the proppant in step 4 is 1-10kg/m2。
11. The preferred method of unconventional reservoir fracturing modifier proppant of claim 1, wherein the hydraulic fracture optimization design software of step 5 is FracPT or StimPlan software.
12. The unconventional reservoir fracturing modification proppant selection method as set forth in any one of claims 1-11, wherein the specific step of fracture simulation in step 5 is to set proppant parameters according to the experimental data obtained in step 4, and then to develop fracture simulation.
13. Use of the unconventional reservoir fracture modifying proppant preferably as set forth in any one of claims 1-12 in an unconventional oil and gas well.
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| CN104358554A (en) * | 2014-12-09 | 2015-02-18 | 中国石油集团川庆钻探工程有限公司 | Method applied to evaluation of flow conductivity of shale-gas-combined sand fracturing fracture |
| CN105134158A (en) * | 2015-08-26 | 2015-12-09 | 中国石油天然气股份有限公司 | Fracturing method for supplementing stratum energy of dense oil reservoir |
| US20160145976A1 (en) * | 2013-08-30 | 2016-05-26 | Landmark Graphics Corporation | Reservoir simulator, method and computer program product to determine proppant damage effects on well production |
| CN107085638A (en) * | 2017-04-17 | 2017-08-22 | 西南石油大学 | A kind of hydraulic fracturing proppants parameter optimization method |
| CN110469303A (en) * | 2019-07-04 | 2019-11-19 | 西南石油大学 | A kind of volume fracturing method for optimally designing parameters based on four classes transformation volume |
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Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20160145976A1 (en) * | 2013-08-30 | 2016-05-26 | Landmark Graphics Corporation | Reservoir simulator, method and computer program product to determine proppant damage effects on well production |
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| CN105134158A (en) * | 2015-08-26 | 2015-12-09 | 中国石油天然气股份有限公司 | Fracturing method for supplementing stratum energy of dense oil reservoir |
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