CN110702484B - Method for calculating in-situ porosity and establishing water saturation of water-containing dissolved salt reservoir core - Google Patents
Method for calculating in-situ porosity and establishing water saturation of water-containing dissolved salt reservoir core Download PDFInfo
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 81
- 150000003839 salts Chemical class 0.000 title claims abstract description 56
- 238000011065 in-situ storage Methods 0.000 title claims abstract description 20
- 238000000034 method Methods 0.000 title claims abstract description 11
- 239000011435 rock Substances 0.000 claims abstract description 44
- 239000008398 formation water Substances 0.000 claims description 36
- 238000002425 crystallisation Methods 0.000 claims description 23
- 230000008025 crystallization Effects 0.000 claims description 23
- 238000002474 experimental method Methods 0.000 claims description 19
- 230000033558 biomineral tissue development Effects 0.000 claims description 12
- 238000012360 testing method Methods 0.000 claims description 11
- 150000001875 compounds Chemical class 0.000 claims description 9
- 239000011148 porous material Substances 0.000 claims description 8
- 239000000835 fiber Substances 0.000 claims description 6
- 238000010521 absorption reaction Methods 0.000 claims description 4
- 238000007789 sealing Methods 0.000 claims description 4
- 239000012530 fluid Substances 0.000 claims description 3
- 229910052500 inorganic mineral Inorganic materials 0.000 claims description 3
- 239000011707 mineral Substances 0.000 claims description 3
- 238000005096 rolling process Methods 0.000 claims description 3
- 238000005185 salting out Methods 0.000 claims description 3
- 229920006395 saturated elastomer Polymers 0.000 claims description 3
- 238000002791 soaking Methods 0.000 claims description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 abstract description 6
- 239000003345 natural gas Substances 0.000 abstract description 3
- 239000007789 gas Substances 0.000 description 10
- 238000011161 development Methods 0.000 description 4
- 230000018109 developmental process Effects 0.000 description 4
- 230000005611 electricity Effects 0.000 description 4
- 230000009286 beneficial effect Effects 0.000 description 2
- 230000008021 deposition Effects 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 238000005406 washing Methods 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 239000012153 distilled water Substances 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000003079 shale oil Substances 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
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- G01N15/088—Investigating volume, surface area, size or distribution of pores; Porosimetry
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- G01N25/147—Investigating or analyzing materials by the use of thermal means by using distillation, extraction, sublimation, condensation, freezing, or crystallisation by cristallisation
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- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
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- G01N33/246—Earth materials for water content
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Abstract
The invention discloses a method for calculating in-situ porosity and establishing water saturation of a water-containing soluble salt reservoir rock core, which relates to the field of rock core analysis of oil and natural gas tight reservoirs.
Description
Technical Field
The invention relates to a method for calculating the in-situ porosity and establishing the water saturation of a water-containing soluble salt reservoir core in the field of oil and natural gas tight reservoir core analysis, and belongs to an experimental method in the aspect of core analysis in the process of oil and natural gas exploration and development.
Background
The unconventional oil gas in China has abundant resource amount, great potential and wide prospect. The output of tight sandstone oil gas, shale oil gas, coal bed gas and carbonate oil gas is continuously increased, and the development of unconventional oil gas resources becomes an indispensable part in the energy pattern of China. When an unconventional oil and gas reservoir is formed in a deposition environment such as a sea phase or a salinized lake, a large amount of water-soluble salt is formed in the reservoir, so that the salinity of formation water is high, and in the process that the core of the water-containing water-soluble salt reservoir is taken from an in-situ temperature pressure condition to a ground temperature pressure condition, the salt is crystallized to cause the pore structure of the core to change, so that the porosity is changed. However, obtaining the core in-situ porosity of a water-containing soluble salt reservoir plays an important role in establishing the water saturation, and the establishment of the core water saturation is the basis for developing a tight reservoir rock electricity experiment. The rock electricity experiment is used as an important means for rock physics research, 4 key parameters in an Archie formula are solved mainly by measuring parameters such as porosity, resistivity, saturation and the like of rock, and then the oil-gas saturation of a stratum is calculated. From the perspective of reservoir protection, the rock-electricity experiment of the water-containing soluble salt reservoir core is carried out after the water saturation of the core is established by using the salinity of the formation water, the rock-electricity experiment accords with reservoir conditions, compared with distilled water, the rock-electricity experiment does not change the pore structure of the water-containing soluble salt reservoir core, and the influence on the pore size is small. Obtaining in-situ core porosity of a reservoir and establishing the required water saturation are of great significance to the development of tight hydrocarbon reservoirs.
The conventional porosity testing method reflects the visual porosity of a rock sample, and in the process of taking an original rock sample of a water-containing salt-soluble reservoir to the ground, salt crystallization can occur inside the rock sample to cause the porosity of the rock sample to change, so that the conventional testing method cannot reflect the original porosity and also influences the establishment of water saturation.
Disclosure of Invention
The invention aims to lay a foundation for the development of subsequent rock-electricity experiments of the compact reservoir through a method for calculating the in-situ porosity and establishing the water saturation of the rock core of the water-containing soluble salt reservoir.
The invention is realized by the following technical scheme:
step 1, selecting a representative core of a water-containing soluble salt reservoir and testing the porosity of the core
Calculating the apparent volume V of the corecoreDetermining volume V of formation water with completely saturated corefluidAnd core density rho, and analyzing the salinity C' of the formation water produced on the surface of the water-containing soluble salt reservoir;
step 2, analyzing the type and proportion of reservoir water soluble salt minerals, preparing compound water soluble salt for experiments, completely dissolving the compound water soluble salt, developing compound water soluble salt crystallization experiments, analyzing the crystallization degree of formation water from the reservoir conditions to the ground conditions, recording a salt crystallization proportion coefficient eta, wherein the salt crystallization proportion coefficient eta is the mass ratio of the crystallization salting-out amount to the water soluble salt in the initial solution;
step 3, calculating the formation water mineralization degree C by using the formula (1) and calculating the rock core in-situ porosity by using the formula (2) in combination with the salt crystallization ratio coefficient eta
Step 4, determining the water saturation to be established, determining the pore volume through the in-situ porosity of the rock core, determining the volume and the quality of formation water used for establishing the water saturation under the condition of the formation water mineralization, soaking fibers by simulated formation water prepared according to the formation water mineralization, rolling the rock core on the fibers, and enabling two ends of the rock core not to contact water;
step 5, repeating the step 4 until the water absorption quality of the rock sample reaches the stratum water quality required for establishing the water saturation, and then sealing and storing the rock sample to ensure that water is absorbed and dispersed in the rock core;
and 6, checking the quality of the rock core to ensure that the required rock core water saturation is established.
Compared with the prior art, the invention has the following beneficial effects:
(1) and determining the accuracy of the calculation of the in-situ porosity of the water-containing dissolved salt reservoir. When an unconventional oil and gas reservoir is formed in a deposition environment such as a sea phase or a salinized lake, a large amount of water-soluble salt is formed in the reservoir, so that the salinity of formation water is high, and in the process that a core of the water-containing water-soluble salt reservoir is taken from an in-situ temperature pressure condition to a ground temperature pressure condition, the porosity of the core is changed due to salt crystallization, so that the porosity is changed, and the porosity test is inaccurate. Meanwhile, the in-situ core porosity is acquired, so that the volume of formation water used for determining the water saturation under the condition of the formation water salinity is facilitated when the core is used for establishing the water saturation.
(2) The objectivity of the evaluation result of the rock electricity experiment is improved. The rock electricity experiment is used as an important means for rock physics research, 4 key parameters in an Archie's formula are solved mainly by measuring parameters such as porosity, resistivity and saturation of rock, and then the oil-gas saturation of the stratum is accurately calculated. From the perspective of reservoir protection, the rock-electricity experiment of the water-containing soluble salt reservoir core is carried out after the water saturation of the core is established by using the salinity of the formation water, the rock-electricity experiment accords with the real conditions of the reservoir, the pore structure of the water-containing soluble salt reservoir core cannot be changed, and the influence on the pore size is small.
(3) The inconvenience and the error of manual porosity testing caused by the salt washing on the porosity testing are avoided. According to the method, the formation water salinity of the water-containing soluble salt reservoir is obtained through the produced water salinity and the salt crystallization proportionality coefficient, then the in-situ porosity of the water-containing soluble salt reservoir is calculated through the formation water salinity and the salt crystallization proportionality coefficient, and a porosity test experiment is carried out without salt washing.
Detailed Description
In order to explain technical characteristics, purposes and beneficial effects of the invention more clearly, the content and characteristics of the invention are further explained in detail by combining specific parameters and embodiments, and the specific steps are as follows:
step 1, selecting a representative core of a water-containing soluble salt reservoir and testing the porosity of the core
Calculating the apparent volume V of the corecoreAnd determining the volume V of the formation water with the completely saturated corefluidAnd core density rho, and testing the salinity C' of the formation water produced on the ground of the water-containing soluble salt reservoir by adopting an atomic absorption spectrophotometer;
step 2, analyzing the type and proportion of reservoir water soluble salt minerals by XRD, preparing compound water soluble salt for experiment, completely dissolving the compound water soluble salt, developing a compound water soluble salt crystallization experiment, analyzing the crystallization degree of produced water from formation water under reservoir conditions to ground temperature and pressure conditions, recording a salt crystallization proportion coefficient eta, wherein the salt crystallization proportion coefficient eta is the mass ratio of the crystallization salting-out amount to the water soluble salt in the initial solution;
step 3, calculating the formation water mineralization degree C by using the formula (1) in combination with the salt crystallization proportional coefficient eta, and carrying the formation water mineralization degree C calculated in the formula (1) into the formula (2) to calculate the in-situ porosity of the rock core
Step 4, determining the water saturation to be established, determining the pore volume through the in-situ porosity of the rock core, determining the volume and the quality of formation water used for establishing the water saturation under the condition of the formation water mineralization, soaking fibers by simulated formation water prepared according to the formation water mineralization, rolling the rock core on the fibers, and enabling two ends of the rock core not to contact water;
step 5, repeating the step 4 until the water absorption quality of the rock sample reaches the formation water quality required for establishing the water saturation, and then putting the rock sample into a sealing bag for sealing and storing to ensure that water is absorbed and dispersed in the rock core;
and 6, checking the quality of the rock core to ensure that the correct water saturation is established.
According to the invention, the formation water mineralization is determined through a crystallization experiment, the in-situ porosity of the rock core is calculated based on the formation water mineralization, and the water saturation of the rock core is established, so that the objective accuracy of the rock core is ensured. In addition, the defects of inaccurate conventional porosity test and water saturation establishment of the water-containing soluble salt reservoir are overcome.
The above embodiments have been described in detail with reference to specific parameters and examples, but the present invention is not limited to the above embodiments, and the experimental conditions and objects can be flexibly changed without departing from the scope of the present invention, which falls within the protection scope of the present invention.
Claims (1)
1. The method for calculating the in-situ porosity and establishing the water saturation of the core of the water-containing dissolved salt reservoir comprises the following steps:
step 1, selecting a representative core of a water-containing soluble salt reservoir and testing the porosity of the core
Calculating the apparent volume V of the corecoreDetermining volume V of formation water with completely saturated corefluidAnd core density rho, and analyzing the salinity C' of the formation water produced on the surface of the water-containing soluble salt reservoir;
step 2, analyzing the type and proportion of reservoir water soluble salt minerals, preparing compound water soluble salt for experiments, completely dissolving the compound water soluble salt, developing compound water soluble salt crystallization experiments, analyzing the crystallization degree of formation water from the reservoir conditions to the ground conditions, recording a salt crystallization proportion coefficient eta, wherein the salt crystallization proportion coefficient eta is the mass ratio of the crystallization salting-out amount to the water soluble salt in the initial solution;
step 3, calculating the formation water mineralization degree C by using the formula (1) and calculating the rock core in-situ porosity by using the formula (2) in combination with the salt crystallization ratio coefficient eta
Step 4, determining the water saturation to be established, determining the pore volume through the in-situ porosity of the rock core, determining the volume and the quality of formation water used for establishing the water saturation under the condition of the formation water mineralization, soaking fibers by simulated formation water prepared according to the formation water mineralization, rolling the rock core on the fibers, and enabling two ends of the rock core not to contact water;
step 5, repeating the step 4 until the water absorption quality of the rock sample reaches the stratum water quality required for establishing the water saturation, and then sealing and storing the rock sample to ensure that water is absorbed and dispersed in the rock core;
and 6, checking the quality of the rock core to ensure that the required rock core water saturation is established.
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| CN112964604A (en) * | 2021-03-25 | 2021-06-15 | 西南石油大学 | Rock contact angle testing device and method considering water saturation and adsorbed gas |
| CN113092337B (en) * | 2021-04-08 | 2022-01-28 | 西南石油大学 | Method for establishing initial water saturation of compact rock core under in-situ condition |
| CN115059460B (en) * | 2022-07-14 | 2024-05-03 | 重庆大学 | Method for reducing self-water absorption of hydraulically fractured shale reservoir |
| CN116050629B (en) * | 2023-01-18 | 2023-09-12 | 重庆科技学院 | Dynamic prediction method for storage capacity of gas storage in consideration of formation water evaporation salting-out |
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