CN113338900A - Method for scientifically calculating soaking time based on rock skeleton theory - Google Patents
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- 238000002791 soaking Methods 0.000 title claims abstract description 81
- 239000011435 rock Substances 0.000 title claims abstract description 43
- 238000000034 method Methods 0.000 title claims abstract description 28
- 230000036571 hydration Effects 0.000 claims abstract description 21
- 238000006703 hydration reaction Methods 0.000 claims abstract description 21
- 238000002474 experimental method Methods 0.000 claims abstract description 16
- 238000010606 normalization Methods 0.000 claims abstract description 12
- 238000010276 construction Methods 0.000 claims abstract description 11
- 238000013461 design Methods 0.000 claims abstract description 8
- 230000005764 inhibitory process Effects 0.000 claims abstract description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 27
- 239000004927 clay Substances 0.000 claims description 23
- 239000012530 fluid Substances 0.000 claims description 19
- 239000007788 liquid Substances 0.000 claims description 8
- 238000012937 correction Methods 0.000 claims description 7
- 238000002347 injection Methods 0.000 claims description 6
- 239000007924 injection Substances 0.000 claims description 6
- 230000000903 blocking effect Effects 0.000 claims description 4
- 238000004364 calculation method Methods 0.000 claims description 4
- 239000011159 matrix material Substances 0.000 claims description 4
- 238000004458 analytical method Methods 0.000 claims description 3
- 230000008859 change Effects 0.000 claims description 3
- 230000001629 suppression Effects 0.000 claims description 3
- 238000007906 compression Methods 0.000 claims description 2
- 230000035699 permeability Effects 0.000 abstract description 6
- 230000000694 effects Effects 0.000 abstract description 5
- 238000005553 drilling Methods 0.000 abstract description 3
- 230000008569 process Effects 0.000 abstract description 3
- 239000003079 shale oil Substances 0.000 abstract description 3
- 230000009466 transformation Effects 0.000 abstract 1
- 239000007789 gas Substances 0.000 description 15
- 238000011161 development Methods 0.000 description 9
- 150000002500 ions Chemical class 0.000 description 8
- 239000002734 clay mineral Substances 0.000 description 5
- 238000004519 manufacturing process Methods 0.000 description 5
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 238000003825 pressing Methods 0.000 description 4
- 230000007547 defect Effects 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 201000004569 Blindness Diseases 0.000 description 2
- 150000001767 cationic compounds Chemical class 0.000 description 2
- 230000002401 inhibitory effect Effects 0.000 description 2
- 229910001411 inorganic cation Inorganic materials 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 239000010453 quartz Substances 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000012634 fragment Substances 0.000 description 1
- 238000005213 imbibition Methods 0.000 description 1
- 230000008676 import Effects 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
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- 239000011707 mineral Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 239000000126 substance Substances 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
- E21B47/00—Survey of boreholes or wells
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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
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Abstract
The invention provides a method for scientifically calculating the soaking time based on a rock skeleton theory, which is a method for achieving the optimal hydration effect of shale by scientifically calculating the soaking time to achieve the hydration expansion purpose of forming a complex gap net to the maximum extent on the basis of keeping a shale skeleton structure due to inherent characteristics of permeability, disintegration, softening property and expansion of shale when shale oil and gas is subjected to fracturing transformation. According to the method, the soaking time is calculated by introducing a pressure normalized increment, rock debris (rock cores) at the front end, the middle end and the rear end of a well drilling process are required to be collected before site construction to carry out an indoor soaking experiment, and the shale soaking softening time and the shale soaking disintegration time in a pressure normalized increment correlation equation are obtained; and then obtaining an ion inhibition coefficient and basic parameters according to geological data, fracturing design and logging comprehensive interpretation, determining pressure normalization increments of different soaking times, and performing curve fitting on the pressure normalization increments to further obtain the optimal soaking time of the well.
Description
Technical Field
The invention relates to the field of shale gas exploitation, in particular to a method for scientifically calculating soaking time based on a rock skeleton theory after fracturing modification.
Background
In recent years, with the rapid development of national economy, the demand of petroleum and natural gas is increased, the yield of domestic conventional oil gas cannot meet the demand, the supply and demand situation of oil gas resources is severe day by day, the oil gas import quantity is increased year by year, and the field of domestic oil gas exploration and development is urgently needed to be widened. Due to the severe current energy situation, the unconventional shale reservoirs are gradually concerned, the exploration and development of shale oil-gas resources are enhanced, the defects of the conventional oil-gas resources can be overcome, the sustainable development of the oil-gas industry is promoted, and the method has important significance for improving the energy structure of China and guaranteeing the national energy supply safety.
Compared with the conventional reservoir, the shale reservoir has the problems of complex reservoir environment, small permeability and porosity, poor fluid mobility, strong heterogeneity, reservoir lithology sensitivity and the like. Although shale oil and gas resources in China are rich, the shale oil and gas resources have the problems of high exploration and development difficulty, late start, low research degree, long construction period, high construction cost, fast yield reduction after production, short stable production period and the like.
The hydraulic fracturing is one of the main means of shale development in China at present, and due to the geological characteristics and the fracturing process of a shale reservoir, a shale oil-gas well has the characteristics of low flowback rate and high yield after the hydraulic fracturing, reduction of water yield and increase of gas production and large difference of flowback rate after soaking and the like. Relevant data show that soaking after fracturing modification of the shale reservoir is beneficial to improving the yield.
The current method for determining the soaking time has single consideration, the most common method is to determine the soaking time according to the development progress of an oil field, the result is artificial blindness and randomness, the total and creep volume of a crack are calculated according to the physical property parameters and fracturing fluid performance parameters of a stratum, and the soaking time is calculated according to the rock imbibition speed.
The shale has the characteristics of water permeability, expansibility, disintegrability and softening property, the main components of the shale are quartz and clay minerals, the clay minerals are non-water-stable, the quartz is water-stable, the shale can be subjected to hydration expansion after being soaked in fracturing fluid, the strength of the shale subjected to hydration expansion is reduced, a complex seam net is formed, the framework plays a supporting role, and after the fracturing fluid for soaking the shale is excessive, the clay minerals in the shale are subjected to hydration expansion excessively, so that the shale framework collapses, the shale disintegrates, and the formed complex seam net disappears. In order to achieve the best yield-increasing effect, the hydration expansion effect of the shale needs to form a complex seam network to the maximum extent on the basis of keeping the shale skeleton force, the hydration shale matrix has micro-seams to communicate natural cracks, bedding and faults, the micro-seams have certain roughness as much as possible, and the self-permeability is improved. The generation of micro-pores and cracks can not only improve natural gas seepage channels, but also facilitate the conversion of adsorbed gas to free gas and improve the yield of oil and gas wells. The central part of the modified rock mass is divided into fine rock blocks, so that the reserve of the deep part of the reservoir layer participates in the transportation to the shaft to become a component part of daily output. Not only can ensure enough single well output, but also greatly improves the recovery ratio of the modified stratum in a short time, thereby ensuring the stable output and improving the utilization degree of the reservoir in the short time. However, due to the development of multi-scale microscopic pores and multi-component minerals in the shale, the interaction mechanism of the shale and the fracturing fluid is very complex, and the hydration and expansion effects of the shale are difficult to quantitatively characterize. At present, the determination of the stewing time after shale modification is not a method for determining the stewing time by using shale softening property and disintegration as identification hydration degrees on the basis of a shale skeleton theory.
Disclosure of Invention
The invention provides a method for scientifically calculating soaking time based on a rock skeleton theory, in particular to a method for scientifically calculating soaking time based on a rock skeleton integrity keeping theory, which aims to solve the problems that in the prior art, the soaking time is determined mainly by depending on field experience, development progress and engineering parameters, great blindness and randomness exist, and the yield of a single well is not ideal after soaking.
The technical scheme is as follows:
a method for scientifically calculating the soaking time based on a rock skeleton theory comprises the following steps:
s1: the following basic parameters are obtained according to the comprehensive interpretation of the logging information: porosity of target layer
Clay content VclayNatural fracture and matrix seepage coefficient RoSlope m of water loss of clay bound waterCBW；
S2: the following data were obtained from the fracture design: temporarily blocking the steering stage number E, the injection liquid amount and the ion inhibition coefficient K in the single slit;
s3: obtaining rock debris or a rock core of a target layer, carrying out an indoor soaking experiment and carrying out experiment result analysis to obtain the following data: soaking shale for softening time B and soaking shale for disintegrating time C;
s4: calculating the total volume H of the fracture according to the logging information and the fracturing design;
s5: obtaining according to site construction parameters: slope G of post-compression pressure drop versus time;
s6: determining a hydration expansion correction coefficient D;
s7: the above data was substituted into the following equation for calculation of the normalized increment of pressure:
wherein t represents the time from fracturing to well opening and flowback, namely the soaking time, and F represents the ratio of the flowback volume to the injection liquid volume.
Further, in step S1, obtaining the basic parameters according to the comprehensive interpretation of the logging data: water saturation, clay irreducible water saturation, and then determining the clay irreducible water loss slope m using the water saturation and the clay irreducible water saturationCBW。
Further, in step S2, information on the type of the target well fracturing fluid is acquired, and an indoor experiment is performed to measure the ion suppression coefficient K.
Further, in step S4, the total fracture volume is calculated by using HFracproPT software.
Further, in step S5, the slope G of the pressure drop after pressure drop with time is determined according to the change of the pressure after pump stop in the field construction.
Further, in step S7, after different soaking times are substituted, a pressure normalization increment is calculated, where the pressure normalization increment data is parabolic, and the time when the amplitude of the pressure normalization increment becomes small is the optimal soaking time.
The method indirectly calculates the optimal soaking time by introducing the pressure normalized increment, realizes the accurate determination of the optimal soaking time by a formula for specifically calculating the soaking time, can calculate the optimal soaking time on the basis of the defect that the soaking time is too long or too short, and simultaneously considers the influence of field construction on the soaking time, and comprises the following steps: pressure drop after pressing, type of fracturing fluid, temporary plugging stage number and temporary plugging fluid amount.
The method saves time, improves efficiency, perfects the content of various factors, can effectively determine the accuracy, increases the initial yield of a single well, prolongs the stable production period, improves the recovery ratio and ensures the stable production.
Drawings
FIG. 1 is a flow chart diagram of the scientific calculation method of the soaking time based on the rock skeleton theory.
Detailed Description
The method for scientifically calculating the soaking time based on the rock skeleton theory indirectly calculates the optimal soaking time by introducing the pressure normalized increment, and when the amplitude of the pressure normalized increment is obviously reduced, the corresponding time is the optimal soaking time.
Wherein the rock skeleton integrity theory is as follows: the complete shale is composed of shale clastic particles, cement and miscellaneous base, the shale framework makes the shale have a hard structure, and fine mechanical mixed clay substances, natural micro-cracks and capillaries are filled among the framework particles under the micro environment. Because shale has permeability, expansibility, disintegratability and softening property, after hydration expansion occurs, the shale skeleton strength is reduced, a large number of micro cracks are generated, if the hydration expansion time is too long or the liquid amount is too much, the shale skeleton strength is continuously reduced, finally the shale is disintegrated, and the micro cracks disappear. Therefore, soaking is carried out on the basis of keeping the shale framework complete and not collapsing.
The invention relies on the softening property, the disintegration property and the expansibility of the shale, and because of the disintegration property, the integrity of the shale skeleton must be kept as the support of the hydration expansion effect, so that the rock cannot collapse after the braising is formed to form a complex seam network, and the softening property and the expansibility of the rock are subjected to indoor experiments.
Furthermore, the invention uses the pressure normalized increment as the vertical axis and the soaking time as the horizontal axis to draw a curve, and the time when the increasing amplitude of the curve is obviously reduced (namely the time when the curve tends to be flat) is the optimal soaking time.
As shown in figure 1, the method firstly obtains rock debris (core), geological data, fracturing design, comprehensive well logging interpretation and field construction parameters of a target well, and then comprises the following steps:
s1: the following basic parameters are obtained according to the comprehensive interpretation of the logging information: porosity of target layer
Clay content VclayNatural fracture and matrix seepage coefficient RoWater saturation, clay irreducible water saturation.
Determination of clay irreducible water loss slope m using water saturation and clay irreducible water saturationCBWAnd drawing a straight line by taking the water saturation as a vertical axis and the irreducible water saturation as a horizontal axis, wherein the slope of the straight line is the water loss slope of the clay irreducible water.
S2: the following data were obtained from the fracture design: the temporary blocking steering stage number E, the injection liquid amount and the ion inhibition coefficient K in the single slit.
The temporary plugging steering stage number E in the single seam, and the data source of the injected liquid amount are designed for the fracturing of the target well and are commonly described in the field.
Furthermore, the ion suppression coefficient K is measured by obtaining the type information of the target well fracturing fluid and carrying out an indoor experiment.
The information of the type of the fracturing fluid is obtained mainly for obtaining inorganic cation K in the fracturing fluid+、Na+、Ca2+Because the inorganic cations have an inhibiting effect on the hydration expansion of the shale, the ion inhibition coefficient K needs to be determined through an indoor experiment. The determination method comprises the following steps: and (3) soaking two groups of rock fragments or rock cores with the same volume of the target layer in clear water and fracturing fluid respectively, measuring the volume expansion difference of the two groups of rock at the same time, and obtaining the ion inhibition coefficient K according to the difference proportion.
S3: obtaining rock debris or a rock core of a target layer, carrying out an indoor soaking experiment and carrying out experiment result analysis to obtain the following data: shale soaking softening time B and shale soaking disintegration time C.
The shale soaking and softening time B refers to the time that in an indoor soaking experiment, fracturing fluid is in contact with clay minerals in shale, the shale generates hydration expansion, the shale starts to soften and expand, the strength of the shale is reduced, the whole structure is converted from compact to loose, and micro cracks start to be generated.
The shale soaking disintegration time C is the time that after shale is softened and expanded to generate a large number of micro cracks in an indoor soaking experiment, a fracturing fluid continuously contacts and reacts with the shale, the strength of the shale is continuously reduced to cause the shale framework to collapse, and the large number of micro cracks generated in the early stage disappear.
The target stratum rock debris or the rock core is commonly described in the field, the rock debris is obtained through returning rock debris in the drilling process, and the rock core is obtained through drilling of the rock core.
The indoor soaking experiment refers to soaking a plurality of groups of target stratum rock debris or rock cores by using field fracturing fluid for different soaking times. And observing the soaked and un-soaked rock debris or rock core through a scanning electron microscope to determine the soaking softening time and the soaking disintegration time.
S4: and (4) calculating the total volume H of the fracture by using software according to the logging information and the fracturing design, and simultaneously considering the inhibiting effect of ions on hydration expansion of the clay minerals.
In the step, FracpropT software is used for calculating the total volume of the fracture, the software is common software, and the fracture morphology (fracture parameters such as fracture height, fracture length and fracture width) under different scales can be simulated by combining different fracturing fluids and proppants according to different stratum parameters (Young modulus, fracture toughness, Poisson ratio, permeability, stratum closing pressure and the like) so as to calculate the total volume H of the fracture.
S5: obtaining according to site construction parameters: slope G of pressure drop versus time after pressing.
And the slope G of the pressure drop after the pressure drop and the time is determined according to the change of the pressure after the pump is stopped in site construction. And drawing a straight line of the pressure changing along with the time by taking the pressure after the pump is stopped as a vertical axis and the time as a horizontal axis, wherein the slope of the straight line is G.
S6: determining a hydration expansion correction coefficient D; and because the actual condition of the stratum cannot be simulated by an experiment, a hydration expansion correction coefficient is introduced for correction, and further, the hydration expansion correction coefficient is determined by acquiring the stratum pressure, the stratum temperature and the like according to geological data.
S7: the above data was substituted into the following formula for calculation of the normalized increment of pressure (pnramp):
wherein:
also referred to as average porosity;
Vclayclay content, also known as average total clay;
Rothe permeability coefficient of natural fractures and matrices;
mCBWclay bound water loss slope;
t is the time (days) from the fracturing end to the well opening flowback;
h-total fracture volume;
k, B, C, D, E, F, G are constants used to scale the model:
k: ion inhibition coefficient, laboratory determination;
b: soaking and softening time, and measuring in a laboratory;
c: soaking and disintegrating time, and measuring in a laboratory;
d: a hydration expansion correction factor;
e: temporarily blocking the steering stage number in the single seam;
f: the ratio of the return displacement to the injection liquid amount;
g: slope of pressure drop versus time after pressing.
And t in the above formula is the soaking time, different soaking times are substituted into the above formula to calculate the pressure normalization increment, and the pressure normalization increment data can be found to present a better parabolic shape. And (4) the time when the pressure normalized increment amplitude is obviously reduced is the optimal soaking time.
And then, calculating and fitting the pressure normalized increment of different soaking time by using a computer to obtain the optimal soaking time. Different pressure normalization increments PNR are obtained by inputting different soaking times t into a computer according to the formulaimp. Taking the soaking time t as the horizontal axis, the pressure normalization increment PNRimpThe vertical axis represents a curve.
The method indirectly calculates the optimal soaking time by introducing the pressure normalized increment, realizes the accurate determination of the optimal soaking time by a formula for specifically calculating the soaking time, can calculate the optimal soaking time on the basis of the defect that the soaking time is too long or too short, and simultaneously considers the influence of field construction on the soaking time, and comprises the following steps: pressure drop after pressing, type of fracturing fluid, temporary plugging stage number and temporary plugging fluid amount.
The above-mentioned technology is only a preferred technical case of the present invention, and is not a limitation to the technical solution of the present invention, and any technical solution that can be realized on the basis of the above-mentioned technical solution without creative work should be considered to fall within the protection scope of the patent of the present invention.
Claims (6)
1. A method for scientifically calculating the soaking time based on a rock skeleton theory comprises the following steps:
s1: the following basic parameters are obtained according to the comprehensive interpretation of the logging information: porosity of target layer
Clay content VclayNatural fracture and matrix seepage coefficient RoSlope m of water loss of clay bound waterCBW；
S2: the following data were obtained from the fracture design: temporarily blocking the steering stage number E, the injection liquid amount and the ion inhibition coefficient K in the single slit;
s3: obtaining rock debris or a rock core of a target layer, carrying out an indoor soaking experiment and carrying out experiment result analysis to obtain the following data: soaking shale for softening time B and soaking shale for disintegrating time C;
s4: calculating the total volume H of the fracture according to the logging information and the fracturing design;
s5: obtaining according to site construction parameters: slope G of post-compression pressure drop versus time;
s6: determining a hydration expansion correction coefficient D;
s7: the above data was substituted into the following equation for calculation of the normalized increment of pressure:
wherein t represents the time from fracturing to well opening and flowback, namely the soaking time, and F represents the ratio of the flowback volume to the injection liquid volume.
2. The method for scientifically calculating the soaking time based on the rock skeleton theory according to claim 1, which is characterized in that: in step S1, obtaining basic parameters according to the comprehensive interpretation of the logging data: water saturation, clay irreducible water saturation, and then determining the clay irreducible water loss slope m using the water saturation and the clay irreducible water saturationCBW。
3. The method for scientifically calculating the soaking time based on the rock skeleton theory according to claim 1, which is characterized in that: in step S2, the type information of the target well fracturing fluid is acquired, and an indoor experiment is performed to measure the ion suppression coefficient K.
4. The method for scientifically calculating the soaking time based on the rock skeleton theory according to claim 1, which is characterized in that: in step S4, the total fracture volume is calculated using HFracproPT software.
5. The method for scientifically calculating the soaking time based on the rock skeleton theory according to claim 1, which is characterized in that: in step S5, the slope G of the post-pressure drop with time is determined according to the change in the post-pump-stop pressure during the site operation.
6. The method for scientifically calculating the soaking time based on the rock skeleton theory according to claim 1, which is characterized in that: and step S7, substituting different soaking time, and calculating pressure normalization increment, wherein the pressure normalization increment data is in a parabolic shape, and the time when the amplitude of the pressure normalization increment becomes small is the optimal soaking time.
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| MIANMO MENG,ETC: "The effect of clay-swelling induced cracks on shale permeability during liquid imbibition and diffusion", 《JOURNAL OF NATURAL GAS SCIENCE AND ENGINEERING》 * |
| 王俊杰: "致密砂岩气储层损害评价体系研究", 《中国优秀博士学位论文全文数据库（工程科技Ⅰ辑）》 * |
| 韩慧芬等: "页岩气井返排规律及控制参数优化", 《石油钻采工艺》 * |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN116306385A (en) * | 2023-05-24 | 2023-06-23 | 中国石油大学(华东) | Oil reservoir fracturing imbibition energy increasing numerical simulation method, system, equipment and medium |
| CN116306385B (en) * | 2023-05-24 | 2023-07-28 | 中国石油大学(华东) | Oil reservoir fracturing imbibition energy increasing numerical simulation method, system, equipment and medium |
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