阅读说明：本技术 定量恢复储层流体充注过程的方法 (Method for quantitatively restoring reservoir fluid filling process ) 是由 曲彦胜 张关龙 马雪洁 李园园 肖雄飞 王千军 李佳 赵玉峰 王圣柱 汪誉新 于 2020-02-17 设计创作，主要内容包括：本发明提供一种定量恢复储层流体充注过程的方法,该定量恢复储层流体充注过程的方法包括：步骤1、选取含油岩石样品作为试验样品,将样品分成2份S<Sub>1</Sub>、S<Sub>2</Sub>；步骤2、计算储层中不同期次油孔隙度；步骤3、抽提获得储层中不同期次油样品；步骤4、计算不同期次充注的油藏的成熟度值；步骤5、确定储层中不同期次充注的油气流体充注时期,充注百分比的定量信息。该定量恢复储层流体充注过程的方法为油气勘探中定量分析油气成藏过程提供重要依据。同时,通过认识残余油与可动油的百分比,可以为制定试油方案以及开发方案提供依据,同时为经济评价储量规模提供依据。(The invention provides a method for quantitatively recovering a reservoir fluid filling process, which comprises the following steps: step 1, selecting an oil-bearing rock sample as a test sample, and dividing the sample into 2 parts of S 1 、S 2 (ii) a Step 2, calculating the oil hole clearance of different stages in the reservoir; step 3, extracting to obtain secondary oil samples in different phases in the reservoir; step 4, calculating the maturity values of the oil reservoirs filled in different periods; and 5, determining quantitative information of filling percentage of the oil-gas fluid filled in different periods in the reservoir. The method for quantitatively recovering the reservoir fluid filling process provides an important basis for quantitatively analyzing the oil-gas reservoir forming process in oil-gas exploration. Meanwhile, by recognizing the percentage of the residual oil and the movable oil, a basis can be provided for formulating a test oil scheme and a development scheme, and a basis is provided for economically evaluating the storage scale.)

1. A method of quantitatively restoring a reservoir fluid charge process, the method comprising:

step 1, selecting an oil-bearing rock sample as a test sample, and dividing the sample into 2 parts of S₁、S₂；

Step 2, calculating the oil hole clearance of different stages in the reservoir;

step 3, extracting to obtain secondary oil samples in different phases in the reservoir;

step 4, calculating the maturity values of the oil reservoirs filled in different periods;

and 5, determining quantitative information of filling percentage of the oil-gas fluid filled in different periods in the reservoir.

2. Method for quantitatively restoring a reservoir fluid filling process according to claim 1, characterized in that in step 1, an oil-immersed or oil-blotted rock sample is selected, the sample is divided into 2 portions S₁、S₂In which S is₁The sample is used for testing the percentage of reservoir bitumen and mobile oil in the rock; s₂Sample crushing to obtain the maturity of movable oil, reservoir asphalt and reservoir inclusionThe value is obtained.

3. The method for quantitatively restoring a reservoir fluid charge process according to claim 1, wherein step 2 comprises:

step 21, measuring the movable oil gap percentage in the rock sample;

step 22, the percent porosity of the immobile oil, i.e., reservoir bitumen, in the rock sample is measured.

4. Method for quantitatively restoring a reservoir fluid filling process according to claim 3, characterized in that in step 21, a rock sample S is taken₁Using an extractor and dichloromethane: extracting for 24 hours by using a mixed reagent with the methanol volume ratio of 93: 7;

making the extracted reservoir asphalt-containing sample m into a cylinder, and measuring the diameter d, the height h and the mass m of the cylinder₁(ii) a Injecting with constant-speed constant-pressure pump at a rate of 0.5ml/min under a confining pressure of 2.0MPa to obtain an injection density of 1g/cm³Until injection is impossible, recording the volume of the injected solution as v; weigh mass m after experiment₂(ii) a The porosity is then:

φ_{is movable}I.e. the pore content of mobile oil in the pores of the reservoir rock.

5. The method for quantitatively restoring a reservoir fluid charge process according to claim 4, characterized in that in step 22, a rock sample S is taken₁Continuing with the extractor and dichloromethane: extracting for 15-30 days by using a mixed reagent with the methanol ratio of 93:7 until the dichloromethane reagent is basically colorless after extraction;

injecting the extracted reservoir-containing asphalt sample m 'with a constant-speed constant-pressure pump at a constant-pressure of 2.0MPa and a speed of 0.5ml/min into the sample m' with a density of 1g/cm³Until the solution (2) was not injected, the volume of the injected solution was recorded as v', and the mass m after the experiment was weighed₂', then porosity is:

φ_{general assembly}The sum of the pore contents of the mobile oil and the reservoir asphalt in the reservoir rock pores is obtained;

the ratio of the volume of the pitch in the pores to the volume of the core is:

φ_leaching＝φ_{General assembly}-φ_{Is movable}。

6. The method for quantitatively restoring a reservoir fluid charge process according to claim 1, wherein step 3 comprises:

step 31, sample treatment: sample S₂Hammering, sieving with 80 mesh sieve to obtain sample S larger than 80 mesh_2lAnd sample S of less than 80 mesh_2sRespectively extracting two samples;

step 32, for the sample S larger than 80 meshes_2lWith an extractor and dichloromethane: extracting with 93:7 volume ratio mixed reagent for 96h, crushing into sand particles in a mortar, extracting for 120h, sampling, and obtaining extracted rock sample and chloroform asphalt sample, namely reservoir asphalt E in oil-bearing rock_Leaching；

Step 33, for sample S smaller than 80 meshes_2sWith an extractor and dichloromethane: extracting with 93:7 volume ratio mixed reagent for 96h to obtain extracted rock sample and chloroform asphalt sample, i.e. mobile oil E in oil-bearing rock_{Is movable}；

And step 34, extracting the extracted rock sample for 72 hours, and collecting the extracted asphalt.

7. The method of quantitatively resuming a reservoir fluid filling process according to claim 6, wherein in step 34, after being taken out, the sand grains are soaked with concentrated sulfuric acid and stirred once every one hour, and after two days, the concentrated sulfuric acid and the organic matter are removed with distilled water and then put on a hot plate to evaporate water vapor; after drying, cleaning twenty times by using a dichloromethane reagent in an ultrasonic instrument to ensure that organic matters outside the inclusion body are thoroughly cleaned; taking the last dichloromethane reagentPerforming color quality analysis, wherein experiments show that no organic matter exists outside the inclusion, putting sand grains without the organic matter into a mortar burnt at high temperature for grinding, and opening the inclusion; soaking the powder in dichloromethane solution, pouring the dichloromethane solution containing inclusion and powder into an alumina column, filtering to remove powder, and collecting the dichloromethane solution containing inclusion, i.e. reservoir inclusion oil E in oil-bearing rock_{Package body}。

8. The method for quantitatively restoring a reservoir fluid charge process according to claim 1, characterized in that in step 4, reservoir bitumen E in the oil-bearing rock sample obtained by extraction is extracted_LeachingMovable oil E_{Is movable}Reservoir inclusion oil E_{Package body}Separating group components, carrying out color-mass analysis on the aromatic hydrocarbon compound, and calculating the maturity of the obtained phenanthrene content:

(1) calculating the A-grade phenanthrene indexes of reservoir asphalt, mobile oil and reservoir inclusion oil in rock:

MPI_asphalt＝1.5×[3-MP_Asphalt+2-MP_Asphalt]/[P_Asphalt+9-MP_Asphalt+1-MP_Asphalt]) Formula (3)

MPI_{Is movable}＝1.5×[3-MP_{Is movable}+2-MP_{Is movable}]/[P_{Is movable}+9-MP_{Is movable}+1-MP_{Is movable}]) Formula (4)

MPI_{Package body}＝1.5×[3-MP_{Package body}+2-MP_{Package body}]/[P_{Package body}+9-MP_{Package body}+1-MP_{Package body}]) Formula (5)

MPI_AsphaltRefers to the Meffy index, MPI, of the asphalt_{Is movable}Refers to the methyl phenanthrene index, MPI, of the mobile oil_{Package body}The index refers to the phenanthrene index of a reservoir inclusion oil; MP (moving Picture experts group)_AsphaltMethyl phenanthrene, MP, being pitch_{Is movable}Methyl phenanthrene, MP as a mobile oil_{Package body}Methylphenanthrene, P, being a reservoir inclusion oil_AsphaltIs the phenanthrene content of the bitumen, P_{Is movable}Is the phenanthrene content of the mobile oil, P_{Package body}For reservoir inclusionThe phenanthrene content of the oil;

(2) and (3) calculating the maturity of the reservoir asphalt, the mobile oil and the reservoir inclusion oil in the rock:

reservoir bitumen calculated maturity Rm_Asphalt＝0.6×MPI_Leaching+0.4 equation (6)

Calculating maturity Rm of mobile oil_{Is movable}＝0.6×MPI_{Is movable}+0.4 equation (7)

Calculating the maturity Rm of the inclusion_{Package body}＝0.6×MPI_{Is movable}+0.4 equation (8).

9. The method for quantitatively recovering the reservoir fluid filling process according to claim 1, wherein in step 5, the buried hydrocarbon history of the research area is established by combining the buried history and the thermal history of the research area, and the reservoir bitumen maturity, the mobile oil maturity and the inclusion maturity obtained by calculation are put on the hydrocarbon history map, so that the reservoir bitumen filling period T can be obtained_AsphaltMovable oil filling geological time T_{Is movable}And capturing geological period T of oil-containing inclusion_{Package body}。

Technical Field

The invention relates to the technical field of oil and gas geological exploration, in particular to a method for quantitatively recovering a reservoir fluid filling process.

Background

Many laminated basins often experience a plurality of stages of construction motions, the oil gas filling process is complex, oil gas generated in the early stage is often degraded due to later-stage stratum lifting and denudation and is stored in rock pores in the form of reservoir asphalt, such thick oil or solid asphalt is often difficult to obtain through a conventional oil testing test, and mature oil gas filled in the later stage is high in gasoline ratio and good in mobility and can be produced through reservoir transformation effects such as conventional oil testing or fracturing.

Therefore, a new method for quantitatively recovering the reservoir fluid filling process is invented, and the technical problems are solved.

Disclosure of Invention

The invention aims to provide a method for quantitatively analyzing the oil-gas filling period in a reservoir pore and the oil-gas filling scale.

The object of the invention can be achieved by the following technical measures: a method of quantitatively restoring a reservoir fluid charge process, the method comprising: step 1, selecting an oil-bearing rock sample asTesting the sample by dividing the sample into 2 portions S₁、S₂(ii) a Step 2, calculating the oil hole clearance of different stages in the reservoir; step 3, extracting to obtain secondary oil samples in different phases in the reservoir; step 4, calculating the maturity values of the oil reservoirs filled in different periods; and 5, determining quantitative information of filling percentage of the oil-gas fluid filled in different periods in the reservoir.

The object of the invention can also be achieved by the following technical measures:

in step 1, an oil-immersed or oil-stained rock sample is selected, and the sample is divided into 2S parts₁、 S₂In which S is₁The sample is used for testing the percentage of reservoir bitumen and mobile oil in the rock; s₂And (4) crushing the sample to obtain the maturity values of the movable oil, the reservoir asphalt and the reservoir inclusion.

The step 2 comprises the following steps:

step 21, measuring the movable oil gap percentage in the rock sample;

step 22, the percent porosity of the immobile oil, i.e., reservoir bitumen, in the rock sample is measured.

In step 21, a rock sample S is sampled₁Using an extractor and dichloromethane: extracting for 24 hours by using a mixed reagent with the methanol volume ratio of 93: 7;

making the extracted reservoir asphalt-containing sample m into a cylinder, and measuring the diameter d, the height h and the mass m of the cylinder₁(ii) a Injecting with constant-speed constant-pressure pump at a rate of 0.5ml/min under a confining pressure of 2.0MPa to obtain an injection density of 1g/cm³Until injection is impossible, recording the volume of the injected solution as v; weigh mass m after experiment₂(ii) a The porosity is then:

φ_{is movable}I.e. the pore content of mobile oil in the pores of the reservoir rock.

In step 22, a rock sample S is sampled₁Continuing with the extractor and dichloromethane: extracting for 15-30 days by using a mixed reagent with the methanol ratio of 93:7 until the dichloromethane reagent is basically colorless after extraction;

injecting the extracted reservoir-containing asphalt sample m 'with a constant-speed constant-pressure pump at a constant-pressure of 2.0MPa and a speed of 0.5ml/min into the sample m' with a density of 1g/cm³Until the solution (2) was not injected, the volume of the injected solution was recorded as v', and the mass m after the experiment was weighed₂', then porosity is:

φ_{general assembly}The sum of the pore contents of the mobile oil and the reservoir asphalt in the reservoir rock pores is obtained;

the ratio of the volume of pitch in the pores to the volume of the core (pores) is:

φ_leaching＝φ_{General assembly}-φ_{Is movable}。

The step 3 comprises the following steps:

step 31, sample treatment: sample S₂Hammering, sieving with 80 mesh sieve to obtain sample S larger than 80 mesh_2lAnd sample S of less than 80 mesh_2sRespectively extracting two samples;

step 32, for the sample S larger than 80 meshes_2lWith an extractor and dichloromethane: extracting with 93:7 volume ratio mixed reagent for 96h, crushing into sand particles in a mortar, extracting for 120h, sampling, and obtaining extracted rock sample and chloroform asphalt sample, namely reservoir asphalt E in oil-bearing rock_Leaching；

Step 33, for sample S smaller than 80 meshes_2sWith an extractor and dichloromethane: extracting with 93:7 volume ratio mixed reagent for 96h to obtain extracted rock sample and chloroform asphalt sample, i.e. mobile oil E in oil-bearing rock_{Is movable}；

And step 34, extracting the extracted rock sample for 72 hours, and collecting the extracted asphalt.

In step 34, taking out, soaking the sand grains in concentrated sulfuric acid, stirring once every hour, washing the concentrated sulfuric acid and the organic matters with distilled water after two days, and putting the washed concentrated sulfuric acid and the organic matters on a heating plate to evaporate water vapor; after drying, cleaning twenty times by using dichloromethane reagent in an ultrasonic instrument to ensure that organic matters outside the wrapping body are thoroughly cleanedCleaning; taking a dichloromethane reagent for the last time for color quality analysis, wherein experiments show that no organic matter exists outside the inclusion, putting sand grains without the organic matter into a mortar burnt at high temperature for grinding, and opening the inclusion; soaking the powder in dichloromethane solution, pouring the dichloromethane solution containing inclusion and powder into an alumina column, filtering to remove powder, and collecting the dichloromethane solution containing inclusion, i.e. reservoir inclusion oil E in oil-bearing rock_{Package body}。

In step 4, extracting the reservoir asphalt E in the obtained oil-bearing rock sample_LeachingMovable oil E_{Is movable}Reservoir inclusion oil E_{Package body}Separating group components, carrying out color-mass analysis on the aromatic hydrocarbon compound, and calculating the maturity of the obtained phenanthrene content:

(1) calculating the A-grade phenanthrene indexes of reservoir asphalt, mobile oil and reservoir inclusion oil in rock:

MPI_asphalt＝1.5×[3-MP_Asphalt+2-MP_Asphalt]/[P_Asphalt+9-MP_Asphalt+1-MP_Asphalt]) Formula (3)

MPI_{Is movable}＝1.5×[3-MP_{Is movable}+2-MP_{Is movable}]/[P_{Is movable}+9-MP_{Is movable}+1-MP_{Is movable}]) Formula (4)

MPI_{Package body}＝1.5×[3-MP_{Package body}+2-MP_{Package body}]/[P_{Package body}+9-MP_{Package body}+1-MP_{Package body}]) Formula (5)

MPI_AsphaltRefers to the Meffy index, MPI, of the asphalt_{Is movable}Refers to the methyl phenanthrene index, MPI, of the mobile oil_{Package body}The index refers to the phenanthrene index of a reservoir inclusion oil; MP (moving Picture experts group)_AsphaltMethyl phenanthrene, MP, being pitch_{Is movable}Methyl phenanthrene, MP as a mobile oil_{Package body}Methylphenanthrene, P, being a reservoir inclusion oil_AsphaltIs the phenanthrene content of the bitumen, P_{Is movable}Is the phenanthrene content of the mobile oil, P_{Package body}Phenanthrene oil as reservoir inclusion oilAn amount;

(2) and (3) calculating the maturity of the reservoir asphalt, the mobile oil and the reservoir inclusion oil in the rock:

reservoir bitumen calculated maturity Rm_Asphalt＝0.6×MPI_Leaching+0.4 equation (6)

Calculating maturity Rm of mobile oil_{Is movable}＝0.6×MPI_{Is movable}+0.4 equation (7)

Calculating the maturity Rm of the inclusion_{Package body}＝0.6×MPI_{Is movable}+0.4 equation (8).

In step 5, the buried hydrocarbon history of the research area is established by combining the buried history and the thermal history of the research area, and the reservoir asphalt maturity, the mobile oil maturity and the inclusion maturity which are obtained by calculation are put on a hydrocarbon history map, so that the reservoir asphalt filling period T can be obtained_AsphaltMovable oil filling geological time T_{Is movable}And capturing geological period T of oil-containing inclusion_{Package body}。

The method for quantitatively recovering the reservoir fluid filling process provides quantitative information such as maturity, percentage content and the like of fluid filled in different periods in a reservoir by utilizing geochemical experimental analysis, and comprises the steps of selecting an oil-bearing rock sample as a test sample, and obtaining the percentage contents of pores such as oil filled in different periods in the oil-bearing rock sample and reservoir asphalt by combining batch extraction and mercury intrusion experiments with a pore model; obtaining the maturity values of the oil filled in different periods; quantitative information of filling percentage of hydrocarbon fluid filling periods filled in different periods in the reservoir. According to the method, chloroform extraction, aromatic hydrocarbon chromaticness, porosity measurement and other experiments are organically combined, a calculation model is established, and geological storage history is combined to obtain the oil and gas accumulation process information, so that the key accumulation periods of residual oil and movable oil are judged, and an important basis is provided for quantitative analysis of the oil and gas accumulation process in oil and gas exploration. Meanwhile, by recognizing the percentage of the residual oil and the movable oil, a basis can be provided for formulating a test oil scheme and a development scheme, and a basis is provided for economically evaluating the storage scale.

Drawings

FIG. 1 is a graph of a wood base 1 well hydrocarbon generation history simulation in accordance with an embodiment of the present invention;

FIG. 2 is a flow chart of one embodiment of a method of quantitatively restoring a reservoir fluid charge process of the present invention.

Detailed Description

In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.

As shown in fig. 2, fig. 2 is a flow chart of a method of quantitatively restoring reservoir fluid charge of the present invention.

Step 101, selecting a sample: selecting oil-immersed or oil-blotchy rock sample, and dividing the sample into 2 parts (S)₁、S₂) In which S is₁The sample is used for testing the percentage of reservoir bitumen and mobile oil in the rock; s₂And (4) crushing the sample to obtain the maturity values of the movable oil, the reservoir asphalt and the reservoir inclusion.

Step 102, calculating oil hole clearance of different periods in reservoir

(1) Measuring the movable oil gap percentage in the rock sample: sampling rock sample S₁Using a soxhlet extractor and dichloromethane: methanol 93:7 volume ratio mixed reagent extraction 24 h.

Making the extracted reservoir asphalt-containing sample m into a cylinder, and measuring the diameter d, the height h and the mass m of the cylinder₁. Injecting with KD-100 constant-speed constant-pressure pump at a rate of 0.5ml/min under a confining pressure of 2.0MPa to obtain an injection density of 1g/cm³Until the injection was not possible, the volume of solution injected was recorded as v. Weigh mass m after experiment₂. The porosity is then:

(φ_{is movable}I.e., the pore content of mobile oil in the reservoir rock pores).

(2) Measurement of immobile oil (reservoir bitumen) pore percentage in rock samples: sampling rock sample S₁Continue with soxhlet extractor and dichloromethane: extracting with 93:7 volume ratio mixed reagent for 15-30 days(the specific time is different according to the test result, the dichloromethane reagent is basically colorless after extraction, and the oil gas in the pores can be considered to be completely extracted).

Injecting the extracted reservoir asphalt sample m 'with KD-100 type constant-speed constant-pressure pump under the condition of confining pressure of 2.0MPa and at the speed of 0.5ml/min into the sample m' with the density of 1g/cm³Until the injection was not possible, the volume of solution injected was recorded as v'. Weigh mass m after experiment₂'. The porosity is then:

(φ_{general assembly}I.e., the sum of the pore contents of mobile oil and reservoir bitumen in the reservoir rock pores).

The ratio of the volume of the pitch in the pores to the volume of the core is:

φ_leaching＝φ_{General assembly}-φ_{Is movable}

103, extracting to obtain oil samples of different periods in the reservoir

(1) Sample treatment: another sample (S)₂) Pulverizing into size of semen Sesami-semen Phaseoli Radiati with geological hammer, sieving with 80 mesh sieve to obtain sample (S) larger than 80 mesh_2l) And samples (S) smaller than 80 mesh_2s). Two samples were extracted separately.

(2) For samples larger than 80 mesh (S)_2l) Using a soxhlet extractor and dichloromethane: extracting with 93:7 volume ratio mixed reagent for 96h, crushing into sand particles in a mortar, extracting for 120h, and sampling to obtain extracted rock sample and chloroform asphalt sample (reservoir asphalt E in oil-bearing rock)_Leaching)。

(3) For samples smaller than 80 mesh (S)_2s) Using a soxhlet extractor and dichloromethane: extracting with mixed reagent with methanol 93:7 volume ratio for 96h to obtain extracted rock sample and chloroform bitumen sample (mobile oil E in oil-bearing rock)_{Is movable})。

(4) And extracting the extracted rock sample for 72h, and collecting the extracted asphalt. Taking out, soaking sand grains in concentrated sulfuric acid, and stirring once every two daysAnd (4) washing concentrated sulfuric acid and organic matters with distilled water, and then putting the washed organic matters on a heating plate to evaporate water vapor. And after drying, cleaning twenty times by using a dichloromethane reagent in an ultrasonic instrument to ensure that organic matters outside the inclusion body are thoroughly cleaned. Taking a dichloromethane reagent for the last time for color quality analysis, wherein experiments show that no organic matter exists outside the inclusion, putting sand grains without the organic matter into a mortar burnt at high temperature for grinding, and opening the inclusion. Soaking the powder in dichloromethane solution, pouring the dichloromethane solution containing inclusion and powder into an alumina column, and filtering the powder to obtain the dichloromethane solution containing inclusion. (reservoir inclusion oil in oil-bearing rock E_{Package body})。

Step 104, maturity calculation

Extracting the reservoir asphalt (E) in the obtained oil-bearing rock sample_Leaching) And mobile oil (E)_{Is movable}) Reservoir inclusion oil (E)_{Package body}) Separating the family components, carrying out development color-mass analysis on aromatic compounds, and calculating the maturity of the obtained phenanthrene content:

(1) calculating the A-grade phenanthrene indexes of reservoir asphalt, mobile oil and reservoir inclusion oil in rock:

MPI_asphalt＝1.5×[3-MP_Asphalt+2-MP_Asphalt]/[P_Asphalt+9-MP_Asphalt+1-MP_Asphalt]) Formula (3)

MPI_{Is movable}＝1.5×[3-MP_{Is movable}+2-MP_{Is movable}]/[P_{Is movable}+9-MP_{Is movable}+1-MP_{Is movable}]) Formula (4)

MPI_{Package body}＝1.5×[3-MP_{Package body}+2-MP_{Package body}]/[P_{Package body}+9-MP_{Package body}+1-MP_{Package body}]) Formula (5)

MPI is an English abbreviation of Meffy index, which means that the ratio of different isomers of the aromatic hydrocarbon parameter Meffy in a biomarker compound is used for representing the maturity in crude oil, and MPI_AsphaltMethyl phenanthrene refers to asphaltNumber, MPI_{Is movable}Refers to the methyl phenanthrene index, MPI, of the mobile oil_{Package body}The index refers to the phenanthrene index of a reservoir inclusion oil; MP (moving Picture experts group)_AsphaltMethyl phenanthrene, MP, being pitch_{Is movable}Methyl phenanthrene, MP as a mobile oil_{Package body}Methylphenanthrene, P, being a reservoir inclusion oil_AsphaltIs the phenanthrene content of the bitumen, P_{Is movable}Is the phenanthrene content of the mobile oil, P_{Package body}Is the phenanthrene content of the reservoir inclusion oil;

(2) and (3) calculating the maturity of the reservoir asphalt, the mobile oil and the reservoir inclusion oil in the rock:

reservoir bitumen calculated maturity Rm_Asphalt＝0.6×MPI_Leaching+0.4 equation (6)

Calculating maturity Rm of mobile oil_{Is movable}＝0.6×MPI_{Is movable}+0.4 equation (7)

Calculating the maturity Rm of the inclusion_{Package body}＝0.6×MPI_{Is movable}+0.4 formula (8)

105, determining oil and gas charging periods of different periods

Establishing the buried hydrocarbon history of the research area by combining the buried history and the thermal history of the research area, and calculating the obtained reservoir asphalt maturity (Rm)_Asphalt) Movable oil maturity (Rm)_{Is movable}) Inclusion maturity (Rm)_{Package body}) The period T of reservoir asphalt filling can be obtained by putting the reservoir asphalt into a hydrocarbon generation history map_AsphaltMovable oil filling geological time T_{Is movable}And capturing geological period T of oil-containing inclusion_{Package body}。

In an embodiment applying the invention, taking the pre-tree depression of the bougainvine in the soongar basin Bogeda as an example, since the second fold, the southeast quasiphund area in which the tree depression is located undergoes the Hayside stage movement, the Yinxui stage movement, the Yanshan stage movement and the Himalayan stage movement, and the residual depression mainly in the second fold system of the existing residual stratum is formed. The study is carried out by taking the oil-containing sandstone of the wood base 1-well two-fold flat ground spring group as an object, so that the oil and gas filling period number, the type and the scale of oil filling in the wood base depression are determined, and the significance for determining the exploration potential and the exploration direction of the wood base depression is great.

1. Calculating the percentage of pores of oil filled in different periods and reservoir asphalt and the like in the oil-bearing rock:

selecting a wood base 1 well two-line flat ground spring group oil-impregnated coarse sandstone sample, dividing the oil-impregnated coarse sandstone sample into 2 parts, and testing the porosity of one part:

(1) sampling rock sample S₁Using a soxhlet extractor and dichloromethane: methanol 93:7 volume ratio mixed reagent extraction 24 h. Making the extracted reservoir asphalt-containing sample m into a cylinder, and measuring the diameter d, the height h and the mass m of the cylinder₁. Injecting with KD-100 constant-speed constant-pressure pump at a rate of 0.5ml/min under a confining pressure of 2.0MPa to obtain an injection density of 1g/cm³Until the injection was not possible, the volume of solution injected was recorded as v. Weigh mass m after experiment₂。

Substituting equation (1):

(φ_{is movable}I.e., the pore content of mobile oil in the reservoir rock pores).

(2) Measurement of immobile oil (reservoir bitumen) pore percentage in rock samples: sampling rock sample S₁Continue with soxhlet extractor and dichloromethane: methanol 93:7 volume ratio mixed reagent extraction for 20 days. After extraction, the dichloromethane reagent is basically colorless, and oil gas in pores is considered to be completely extracted.

Injecting the extracted reservoir asphalt sample m 'with KD-100 type constant-speed constant-pressure pump under the condition of confining pressure of 2.0MPa and at the speed of 0.5ml/min into the sample m' with the density of 1g/cm³Until the injection was not possible, the volume of solution injected was recorded as v'. Weigh mass m after experiment₂'. The porosity is then:

(φ_{general assembly}I.e., the sum of the pore contents of mobile oil and reservoir bitumen in the reservoir rock pores).

The ratio of the volume of the pitch in the pores to the volume of the core is:

φ_asphalt＝φ_{General assembly}-φ_{Is movable}＝8.72-7.58＝1.14％

TABLE 1 porosity test chart for wood base 1 well binary system sample

2. Calculation of maturity of different-phase secondary oil samples

(1) Sample treatment: ramus woodii 1 well was loaded with another sample (S)₂) Pulverizing into size of semen Sesami-semen Phaseoli Radiati with geological hammer, sieving with 80 mesh sieve to obtain sample (S) larger than 80 mesh_2l) And samples (S) smaller than 80 mesh_2s). Two samples were extracted separately.

(2) For samples larger than 80 mesh (S)_2l) Using a soxhlet extractor and dichloromethane: extracting with 93:7 volume ratio mixed reagent for 96h, crushing into sand particles in a mortar, extracting for 120h, sampling, and obtaining extracted rock sample and chloroform asphalt sample (reservoir asphalt E in oil-bearing rock)_Leaching)。

(3) For samples smaller than 80 mesh (S)_2s) Using a soxhlet extractor and dichloromethane: extracting with mixed reagent with methanol 93:7 volume ratio for 96h to obtain extracted rock sample and chloroform bitumen sample (mobile oil E in oil-bearing rock)_{Is movable})。

(4) And extracting the extracted rock sample for 72h, and collecting the extracted asphalt. Taking out, soaking the sand grains in concentrated sulfuric acid, stirring once every hour, washing the concentrated sulfuric acid and the organic matters with distilled water after two days, and then putting the washed concentrated sulfuric acid and the organic matters on a heating plate to evaporate water vapor. And after drying, cleaning twenty times by using a dichloromethane reagent in an ultrasonic instrument to ensure that organic matters outside the inclusion body are thoroughly cleaned. Taking a dichloromethane reagent for the last time for color quality analysis, wherein experiments show that no organic matter exists outside the inclusion, putting sand grains without the organic matter into a mortar burnt at high temperature for grinding, and opening the inclusion. Soaking the powder in dichloromethane solution, pouring the dichloromethane solution containing inclusion and powder into alumina column, filtering to remove powder to obtain inclusion-containing solutionDichloromethane solution. (reservoir inclusion oil in oil-bearing rock E_{Package body})。

TABLE 2 data sheet of the secondary oil extracts of different periods

3. Calculation of maturity

Extracting the reservoir asphalt (E) in the obtained oil-bearing rock sample_Asphalt) And mobile oil (E)_{Is movable}) Reservoir inclusion oil (E)_{Package body}) Separating the family components, carrying out development color-mass analysis on aromatic compounds, and calculating the maturity of the obtained phenanthrene content:

(1) calculating the A-grade phenanthrene indexes of reservoir asphalt, mobile oil and reservoir inclusion oil in rock:

MPI_asphalt＝1.5×[3-MP+2-MP]/[P+9-MP+1-MP])

＝1.5×[222+550]/[1495+611+486])＝0.45

MPI_{Is movable}＝1.5×[3-MP+2-MP]/[P+9-MP+1-MP])

＝1.5×[1472+2024]/[2716+2066+1488])＝0.84

MPI_{Package body}＝1.5×[3-MP+2-MP]/[P+9-MP+1-MP])

＝1.5×[62747+76885]/[176486+90636+59243])＝0.79

(2) And (3) calculating the maturity of the reservoir asphalt, the mobile oil and the reservoir inclusion oil in the rock:

reservoir bitumen calculated maturity: rm_Asphalt＝0.6×MPI_Leaching+0.4＝0.6× 0.45+0.4＝0.67

Mobile oil calculated maturity: rm_{Is movable}＝0.6×MPI_{Is movable}+0.4＝0.6× 0.84+0.4＝0.90

And (3) calculating the maturity of the inclusion: rm_{Package body}＝0.6×MPI_{Is movable}+0.4＝0.6× 0.64+0.4＝0.79

TABLE 3 calculation table of maturity of secondary oil in different periods

	Phenanthrene	3-methyl phenanthrene	2-methyl phenanthrene	9-Methylphenyl	1-methyl phenanthrene	MPI	Rm
								EAsphalt	1495	222	550	611	486	0.45	0.67
EIs movable	2716	1472	2024	2066	1488	0.84	0.90
								EPackage body)	176486	62747	76885	90636	59243	0.64	0.79

4. Determining oil and gas charging periods of different periods

The buried history map of the wood rampart 1 well is generated through basin simulation software, the ground temperature gradient refers to research results of Qiuhuang and the like which are aligned to the Song basin in 2000, and the buried hydrocarbon history of the research area is established, as shown in fig. 1, wherein fig. 1 is left: the hydrocarbon evolution history map of the ramon 1 well; and (3) right: the method comprises the steps of (1) putting the calculated reservoir asphalt maturity (0.67%), the movable oil maturity (0.90%) and the inclusion maturity (0.79%) on a hydrocarbon generation history map (figure 1) to obtain a reservoir asphalt filling period T_LeachingIn the geological period T of 190Ma, namely early-middle Jurassic and mobile oil filling_{Is movable}At 140Ma, early chalkiness, geological time T for trapping oil-containing inclusions_{Package body}As far as 160Ma, it is known as late Jurassic.

By carrying out maturity and porosity content measurement of oil gas of different periods of a reservoir stratum on the wood base sunken wood base 1-well oil-immersed crude sandstone sample, the conclusion can be drawn that the wood base sunken binary system undergoes 2-3 times of oil gas filling, the first filling occurs in the early-middle Jurassic state, the filling is about 190Ma till now, the lower Rm of the oil maturity of the filling is about 0.67%, the filling is low-mature thickened oil, and the oil gas filling amount is less. The mature oil is filled in the first period of late Jurassic-early chalkiness, and the maturity Rm is 0.79-0.9%In between, the oil gas filling amount in the period is 6 to 7 times (phi) of the low-viscosity oil in the last period_{Movable (%)}7.58％_，φ_{Asphalt (%)}1.14%). Is currently mobile oil in the pores of rocks.

The oil gas filling period, the filling time, the filling product and the filling amount of the wood base pit are basically determined through the analysis, the oil in the pores of the flat earth spring group reservoir of the wood base pit is mainly filled in a late stage, the content of movable oil is high, and good yield can be obtained through effective reservoir transformation measures, so that the method has important guiding significance for the subsequent resource amount estimation and the formulation of an oil gas exploration deployment and development scheme.

The foregoing is directed to embodiments of the present invention and other modifications, variations, and equivalents thereof, which may be resorted to by those skilled in the art without departing from the spirit and scope of the invention as defined by the appended claims.