CN111929220A - Experimental evaluation method for high-temperature thermal shock permeability-increasing effect of organic-rich shale - Google Patents
Experimental evaluation method for high-temperature thermal shock permeability-increasing effect of organic-rich shale Download PDFInfo
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- 230000035939 shock Effects 0.000 title claims abstract description 48
- 238000011156 evaluation Methods 0.000 title claims abstract description 25
- 230000000694 effects Effects 0.000 title claims abstract description 17
- 230000035699 permeability Effects 0.000 claims abstract description 40
- 238000011065 in-situ storage Methods 0.000 claims abstract description 26
- 230000001965 increasing effect Effects 0.000 claims abstract description 17
- 238000010438 heat treatment Methods 0.000 claims description 16
- 239000011435 rock Substances 0.000 claims description 11
- 230000006641 stabilisation Effects 0.000 claims description 6
- 238000011105 stabilization Methods 0.000 claims description 6
- 238000001035 drying Methods 0.000 claims description 3
- 230000002708 enhancing effect Effects 0.000 claims description 3
- 230000000087 stabilizing effect Effects 0.000 claims description 3
- 230000035515 penetration Effects 0.000 claims description 2
- 239000007789 gas Substances 0.000 abstract description 15
- 238000000034 method Methods 0.000 abstract description 8
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 abstract description 4
- 230000007547 defect Effects 0.000 abstract description 2
- 239000003345 natural gas Substances 0.000 abstract description 2
- 230000009466 transformation Effects 0.000 abstract description 2
- 238000012854 evaluation process Methods 0.000 abstract 1
- 239000003209 petroleum derivative Substances 0.000 abstract 1
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 16
- 229910052757 nitrogen Inorganic materials 0.000 description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 4
- 230000008859 change Effects 0.000 description 3
- 230000009471 action Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000011068 loading method Methods 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 238000001704 evaporation Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000011049 filling Methods 0.000 description 1
- 230000008595 infiltration Effects 0.000 description 1
- 238000001764 infiltration Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000002791 soaking Methods 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
- G01N15/0826—Investigating permeability by forcing a fluid through a sample and measuring fluid flow rate, i.e. permeation rate or pressure change
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N1/00—Sampling; Preparing specimens for investigation
- G01N1/28—Preparing specimens for investigation including physical details of (bio-)chemical methods covered elsewhere, e.g. G01N33/50, C12Q
- G01N1/44—Sample treatment involving radiation, e.g. heat
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Abstract
The invention relates to the field of shale reservoir yield increase transformation in the petroleum and natural gas industry, and provides an experimental evaluation method for high-temperature heat shock permeability-increasing effect of organic-rich shale. By comparing the permeability of the shale under the in-situ condition after high-temperature heat shock with the permeability of the shale under the low confining pressure before the high-temperature heat shock, an evaluation index based on the high-temperature heat shock permeability-increasing multiple under the in-situ condition is formulated, and the permeability-increasing effect grade of the shale after the high-temperature heat shock is divided according to the high-temperature heat shock permeability-increasing multiple under the in-situ condition. The evaluation process combines the actual conditions of the reservoir, the shale high-temperature thermal shock permeability increasing effect under the in-situ condition is evaluated, and the evaluation result is more objective and reliable. The method has strong operability, makes up the defects of the current experimental evaluation method for the high-temperature thermal shock permeability-increasing effect of the shale, and has important significance for predicting the shale gas reservoir productivity, evaluating the reservoir production-increasing operation and the like.
Description
Technical Field
The invention relates to the field of yield increase transformation of oil and natural gas industrial shale reservoirs, in particular to an experimental evaluation method for high-temperature heat shock permeability-increasing effect of organic-rich shale.
Background
Shale gas is hidden in the development process, a horizontal well subsection hydraulic fracturing technology is widely adopted, and the problems of low flowback rate, serious water phase trapping damage and the like are often faced. The problems can be well solved by a reservoir high-temperature heat treatment technology, on one hand, water phase trapping is removed and a gas flow channel is recovered by evaporating water in a near well zone; on the other hand, the thermal expansion of each component of the shale can be utilized, so that a micro-crack network is generated in the shale, a new permeation zone is formed, and the gas seepage capability is further improved. The strength of the permeability increasing effect is an important basis for evaluating the productivity of the shale gas reservoir, so that an objective evaluation method is urgently needed for quantitatively describing the permeability increasing effect of the shale reservoir after high-temperature thermal shock.
At present, many experimental studies on shale high-temperature heat shock permeability increasing are carried out, but few researchers deeply explore evaluation methods and indexes of permeability increasing effects after high-temperature heat shock. The traditional evaluation of the high-temperature heat shock permeation enhancing effect is mostly carried out under low confining pressure, the applied effective stress is not more than 5MPa, and the evaluation result is greatly different from the actual evaluation result. Shale reservoir high temperature thermal shock can produce fracture networks up to millimeter levels. As is known, the conductivity of the fracture network is necessarily influenced by the in-situ effective stress, so that the key factor of the in-situ effective stress is not ignored when the high-temperature thermal shock infiltration enhancement effect is evaluated. Therefore, the method for establishing the experimental evaluation of the high-temperature thermal shock permeability-increasing effect of the shale rich in organic matters under the in-situ effective stress condition has important significance for predicting the shale gas reservoir productivity, evaluating reservoir production-increasing operation and the like.
Disclosure of Invention
The invention aims to provide an experimental evaluation method for a high-temperature thermal shock permeability-increasing effect of a shale reservoir. The method determines the permeability increasing multiple I by measuring the change of permeability of the shale sample under the action of stress after high-temperature heat shockHTSIAs an index evaluation method, and in combination with the relationship between the pore structure and the flow conductivity, the permeability increase is dividedAnd (4) effect grade. The method is characterized in that effective stress of a reservoir under the in-situ condition is simulated after shale is thermally shocked at high temperature as an important point, the effective stress in the rock sample reaches the in-situ effective stress value by gradually increasing confining pressure, and evaluation is carried out according to the ratio of the permeability under the in-situ condition after the high-temperature thermal shock to the permeability of the natural shale sample before the high-temperature thermal shock. In order to achieve the above purpose, the invention is realized by the following technical scheme:
(1) selecting a representative core plunger of a shale reservoir to be evaluated, and drying for 24 hours at the temperature of 60-65 ℃;
(2) taking out the core plunger in the step (1), and measuring the initial permeability (K) of the core plungeros)；
(3) Filling the core plunger in the step (2) into an atmosphere tube type heating furnace, opening valves at two sides, introducing nitrogen from one side, and controlling the flow rate of a controller to slowly drive out air in the tube;
(4) opening an operation interface of the atmosphere tube type heating furnace, and setting high-temperature heat treatment parameters of the shale sample, wherein the initial temperature is 25 ℃, the heat treatment temperature T, the heating rate is 5 ℃/min, and the stabilization time is 4 h;
(5) starting a heat treatment program, and after the thermal stabilization time is finished, turning off a power supply to naturally cool the shale rock sample;
(6) after the rock core in the step (5) is cooled to room temperature, closing the nitrogen cylinder, and taking out the rock core;
(7) loading the rock sample in the step (6) into a rock core holder, opening a confining pressure valve, pumping in confining pressure to a preset value, and closing the confining pressure valve, wherein the stabilization time is not less than 30 min;
(8) opening an inlet end valve, opening an outlet end valve, opening a gas cylinder valve, adjusting the pressure of the inlet end, and stabilizing for 5-10 min;
(9) measuring the flow of the outlet end, and calculating the permeability of the outlet end;
(10) gradually increasing the confining pressure, repeating the steps (8) to (10) until the confining pressure reaches the in-situ effective stress, and recording the permeability K at the momentHTSI；
(11) Closing the gas cylinder, opening the confining pressure valve, slowly unloading the confining pressure and taking out the core;
(12) calculating the in-situ condition of the shale sample after high-temperature heat shock through the formula (1)Low high temperature heat shock penetration multiple IHTSIAnd the permeation enhancing effect by high temperature heat shock was evaluated with reference to table 1.
In the formula: i isHTSIHigh-temperature thermal shock permeation increasing times under the in-situ condition are dimensionless; kHTSIGas permeability, mD, under in-situ effective stress conditions after high temperature heat shock; kogGas permeability, mD, of the natural shale sample at low confining pressure before high temperature heat shock.
TABLE 1 evaluation chart of high-temperature heat shock synergistic effect of organic shale
Compared with the prior art, the invention has the following beneficial effects:
(1) the defects in the field of experimental evaluation of the high-temperature heat shock permeability-increasing effect of the shale are overcome, and particularly the high-temperature heat shock permeability-increasing effect of the shale is evaluated under the simulated in-situ condition;
(2) objective and operable experimental procedures and evaluation indexes are provided for evaluating the high-temperature heat shock permeability increasing effect of the shale;
(3) the method is not only suitable for evaluating the high-temperature heat shock permeability-increasing effect of the shale, but also suitable for evaluating the high-temperature heat shock permeability-increasing effect of other reservoirs.
Drawings
FIG. 1 is a flow chart of an experimental evaluation method for high-temperature thermal stimulation permeability-increasing effect of shale
FIG. 2 is a graph showing permeability change curves of shale under different stress action conditions after high-temperature thermal shock
Detailed Description
In order to verify the reliability of the method, a Longmaxi organic-rich shale sample is selected as an experimental sample, and the permeability increasing effect of the shale sample is evaluated by measuring the permeability of the natural shale sample under low confining pressure before high-temperature heat shock and the permeability under the in-situ effective stress condition after high-temperature heat shock. The specific operation steps are as follows:
(1) selecting a core plunger LMX-1Y (L is 44.12mm, and D is 25.26mm), putting the core plunger LMX-1Y into an oven, drying the core plunger LMX-1Y for 24 hours at the set temperature of 64 ℃, soaking the core plunger LMX-1Y in a 3% KCl solution for 12 hours, and establishing water saturation to enhance the high-temperature heat shock effect;
(2) taking out the dried core, measuring its length, diameter, mass, porosity and initial gas permeability (K)og)；
(3) Putting the core into an atmosphere tube type heating furnace, opening valves at two ends of the heating tube, and connecting one end of the heating tube with a nitrogen cylinder;
(4) adjusting the pressure of a nitrogen cylinder to enable nitrogen to slowly enter the heating pipe, introducing the nitrogen for about 3-4 min, and then discharging air in the pipe;
(5) continuously introducing nitrogen, turning on a power supply, and setting a heat treatment program, wherein the heat treatment program comprises an ambient temperature of 25 ℃, a temperature rise time of 135min, namely a temperature rise rate of 5 ℃/min, a heat treatment temperature of 700 ℃, and a thermal stabilization time of 4 h;
(6) starting heat treatment, and turning off a power supply after the thermal stabilization time is finished so as to naturally cool the rock sample to room temperature;
(7) closing the nitrogen cylinder and the valves at the two ends, taking out the rock core, and loading the rock sample into a triaxial hole permeability measuring instrument;
(8) opening a confining pressure valve, pumping in confining pressure of 4MPa, closing the confining pressure valve, and stabilizing for 40 min;
(9) opening an inlet end valve, opening an air cylinder air valve, and adjusting a pressure reducing valve to enable the pressure of the inlet end to be 0.5 MPa;
(10) after the pressure at the inlet end is stabilized for 8-10 min, the flow Q of the gas at the outlet end is measuredi；
(11) According to the flow rate QiCalculating the permeability of the material, and recording data;
(12) and (4) changing the confining pressure to the next preset pressure point, and repeating the steps (9) to (12). The confining pressure points are set to 4MPa, 6MPa, 8MPa, 10MPa, 12MPa, 15MPa, 20MPa, 25MPa, 30MPa and 40MPa, and the permeability K under the in-situ effective stress condition is recordedHTSI；
(13) According to the measured natural shale sample gas permeability K under the low confining pressure before the shale sample is thermally shocked at high temperatureogAnd high temperature heatGas permeability K under excited in-situ effective stress conditionHTSIThe permeability-increasing index I is calculated by the following formulaHTSIThe method further has evaluation indexes for judging the permeation increasing effect, and the evaluation results are shown in a table 2;
in the formula: i isHTSIHigh-temperature thermal shock permeation increasing times under the in-situ condition are dimensionless; kHTSIGas permeability, mD, under in-situ effective stress conditions after high temperature heat shock; kogGas permeability, mD, of the natural shale sample at low confining pressure before high temperature heat shock.
TABLE 2 evaluation results of shale sample high-temperature heat shock permeability increasing effect
The above embodiments have been described in detail with reference to the drawings and examples, but the present invention is not limited to the above embodiments, which are only illustrative and not restrictive, and those skilled in the art can flexibly change the experimental conditions and analysis methods and objects without departing from the scope of the present invention.
Claims (1)
1. The experimental evaluation method for the high-temperature thermal shock permeability-increasing effect of the shale is characterized by comprising the following steps of:
s1, selecting a representative core plunger of an oil and gas reservoir to be evaluated, carrying out drying pretreatment for 4 hours at the temperature of 60-65 ℃, and measuring the initial permeability K of the core plungerog；
S2, performing high-temperature heat treatment on the rock sample in the S1, wherein the initial temperature is 25 ℃, the heating rate is 5 ℃/min, the heat treatment temperature is T, and the thermal stabilization time is 4 h;
s3, after the heat treatment is finished, after the core is cooled to room temperature, the core is put into a core holder, confining pressure is applied, and the permeability of the core is measured after the core is stabilized for 30 min;
s4, gradually increasing confining pressure, measuring the permeability of the confining pressure after stabilizing for 30min, stopping measuring until the confining pressure reaches the in-situ effective stress, and recording the gas permeability K under the in-situ effective stress condition after high-temperature heat shockHTSI；
S5, slowly unloading confining pressure, and taking out a rock sample after the confining pressure is reduced to 0;
s6, according to the measured natural shale sample gas permeability K under the low confining pressure before the shale sample is thermally shocked at the high temperatureogAnd gas permeability K under in-situ effective stress after high temperature heat shockHTSI(ii) a Calculating the high-temperature heat shock penetration multiple I under the in-situ condition by the formula (1)HTSI；
In the formula: i isHTSIHigh-temperature thermal shock permeation increasing times under the in-situ condition are dimensionless; kHTSIGas permeability, mD, under in-situ effective stress conditions after high temperature heat shock; koθGas permeability, mD, of the natural shale sample at low confining pressure before high temperature heat shock;
s7, and referring to the table 1, evaluating the high-temperature thermal shock permeability increasing effect of the shale.
TABLE 1 evaluation table of high-temperature heat shock permeation enhancing effect of organic shale
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| CN112685920A (en) * | 2021-03-12 | 2021-04-20 | 西南石油大学 | Shale reservoir permeability improvement evaluation method based on ultrahigh temperature heating |
| CN113447421A (en) * | 2021-07-20 | 2021-09-28 | 西南石油大学 | Method for evaluating oxidation, corrosion and infiltration potential of compact coal rock reservoir |
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Application publication date: 20201113 |