CN111577265A - Method for quantitatively restoring reservoir fluid filling process - Google Patents
Method for quantitatively restoring reservoir fluid filling process Download PDFInfo
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- CN111577265A CN111577265A CN202010100881.XA CN202010100881A CN111577265A CN 111577265 A CN111577265 A CN 111577265A CN 202010100881 A CN202010100881 A CN 202010100881A CN 111577265 A CN111577265 A CN 111577265A
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- 238000000034 method Methods 0.000 title claims abstract description 33
- 239000012530 fluid Substances 0.000 title claims abstract description 24
- 238000005429 filling process Methods 0.000 title claims abstract description 12
- 239000011435 rock Substances 0.000 claims abstract description 73
- 238000011049 filling Methods 0.000 claims abstract description 28
- 238000012360 testing method Methods 0.000 claims abstract description 14
- YMWUJEATGCHHMB-UHFFFAOYSA-N Dichloromethane Chemical compound ClCCl YMWUJEATGCHHMB-UHFFFAOYSA-N 0.000 claims description 117
- 239000010426 asphalt Substances 0.000 claims description 112
- YNPNZTXNASCQKK-UHFFFAOYSA-N phenanthrene Chemical compound C1=CC=C2C3=CC=CC=C3C=CC2=C1 YNPNZTXNASCQKK-UHFFFAOYSA-N 0.000 claims description 39
- 239000011148 porous material Substances 0.000 claims description 32
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 27
- 239000003153 chemical reaction reagent Substances 0.000 claims description 27
- 239000000243 solution Substances 0.000 claims description 22
- HEDRZPFGACZZDS-UHFFFAOYSA-N Chloroform Chemical compound ClC(Cl)Cl HEDRZPFGACZZDS-UHFFFAOYSA-N 0.000 claims description 18
- 238000002386 leaching Methods 0.000 claims description 15
- 238000002474 experimental method Methods 0.000 claims description 14
- DOWJXOHBNXRUOD-UHFFFAOYSA-N methylphenanthrene Natural products C1=CC2=CC=CC=C2C2=C1C(C)=CC=C2 DOWJXOHBNXRUOD-UHFFFAOYSA-N 0.000 claims description 13
- 239000000843 powder Substances 0.000 claims description 12
- 239000004576 sand Substances 0.000 claims description 12
- 239000004215 Carbon black (E152) Substances 0.000 claims description 11
- 229930195733 hydrocarbon Natural products 0.000 claims description 11
- 150000002430 hydrocarbons Chemical class 0.000 claims description 11
- 238000004458 analytical method Methods 0.000 claims description 10
- 238000000605 extraction Methods 0.000 claims description 10
- 238000002347 injection Methods 0.000 claims description 10
- 239000007924 injection Substances 0.000 claims description 10
- QAOWNCQODCNURD-UHFFFAOYSA-N sulfuric acid Substances OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 claims description 10
- 239000005416 organic matter Substances 0.000 claims description 9
- 239000004570 mortar (masonry) Substances 0.000 claims description 8
- 238000011160 research Methods 0.000 claims description 8
- 238000005070 sampling Methods 0.000 claims description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 8
- 238000004364 calculation method Methods 0.000 claims description 7
- 238000002791 soaking Methods 0.000 claims description 7
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 claims description 4
- 150000004945 aromatic hydrocarbons Chemical class 0.000 claims description 4
- 238000004140 cleaning Methods 0.000 claims description 4
- 239000012153 distilled water Substances 0.000 claims description 4
- 238000001035 drying Methods 0.000 claims description 4
- 238000001914 filtration Methods 0.000 claims description 4
- 238000000227 grinding Methods 0.000 claims description 4
- 239000002245 particle Substances 0.000 claims description 4
- 238000007873 sieving Methods 0.000 claims description 4
- LOCGAKKLRVLQAM-UHFFFAOYSA-N 4-methylphenanthrene Chemical compound C1=CC=CC2=C3C(C)=CC=CC3=CC=C21 LOCGAKKLRVLQAM-UHFFFAOYSA-N 0.000 claims description 3
- 210000003000 inclusion body Anatomy 0.000 claims description 3
- 238000011161 development Methods 0.000 abstract description 5
- 239000003921 oil Substances 0.000 description 126
- 239000002023 wood Substances 0.000 description 12
- 230000033001 locomotion Effects 0.000 description 5
- 238000005259 measurement Methods 0.000 description 4
- 238000009825 accumulation Methods 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 3
- 238000003756 stirring Methods 0.000 description 3
- 238000005406 washing Methods 0.000 description 3
- 150000001491 aromatic compounds Chemical class 0.000 description 2
- 229910002056 binary alloy Inorganic materials 0.000 description 2
- 238000010298 pulverizing process Methods 0.000 description 2
- 210000000582 semen Anatomy 0.000 description 2
- 230000009466 transformation Effects 0.000 description 2
- -1 Phenanthrene 3-methyl phenanthrene 2-methyl phenanthrene 9-Methylphenyl 1-methyl phenanthrene Chemical compound 0.000 description 1
- 206010037867 Rash macular Diseases 0.000 description 1
- 239000000090 biomarker Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 239000000284 extract Substances 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 description 1
- 229910052753 mercury Inorganic materials 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000004445 quantitative analysis Methods 0.000 description 1
- 244000308427 ramon Species 0.000 description 1
- 235000005828 ramon Nutrition 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000007787 solid 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/02—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
- Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping
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- Fluid Mechanics (AREA)
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Abstract
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 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 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.
Description
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:
φis movableI.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:
φgeneral assemblyThe 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:
φleaching＝φGeneral assembly-φIs 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 mesh2lAnd sample S of less than 80 mesh2sRespectively extracting two samples;
step 32, for the sample S larger than 80 meshes2lWith 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 rockLeaching；
Step 33, for sample S smaller than 80 meshes2sWith 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 rockIs 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 rockPackage body。
In step 4, extracting the reservoir asphalt E in the obtained oil-bearing rock sampleLeachingMovable oil EIs movableReservoir inclusion oil EPackage bodySeparating 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:
MPIasphalt＝1.5×[3-MPAsphalt+2-MPAsphalt]/[PAsphalt+9-MPAsphalt+1-MPAsphalt]) Formula (3)
MPIIs movable＝1.5×[3-MPIs movable+2-MPIs movable]/[PIs movable+9-MPIs movable+1-MPIs movable]) Formula (4)
MPIPackage body＝1.5×[3-MPPackage body+2-MPPackage body]/[PPackage body+9-MPPackage body+1-MPPackage body]) Formula (5)
MPIAsphaltRefers to the Meffy index, MPI, of the asphaltIs movableRefers to the methyl phenanthrene index, MPI, of the mobile oilPackage bodyThe index refers to the phenanthrene index of a reservoir inclusion oil; MP (moving Picture experts group)AsphaltMethyl phenanthrene, MP, being pitchIs movableMethyl phenanthrene, MP as a mobile oilPackage bodyMethylphenanthrene, P, being a reservoir inclusion oilAsphaltIs the phenanthrene content of the bitumen, PIs movableIs the phenanthrene content of the mobile oil, PPackage bodyPhenanthrene 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 RmAsphalt＝0.6×MPILeaching+0.4 equation (6)
Calculating maturity Rm of mobile oilIs movable＝0.6×MPIIs movable+0.4 equation (7)
Calculating the maturity Rm of the inclusionPackage body＝0.6×MPIIs 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 obtainedAsphaltMovable oil filling geological time TIs movableAnd capturing geological period T of oil-containing inclusionPackage 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.
(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:
(φis movableI.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:
(φgeneral assemblyI.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:
φleaching＝φGeneral assembly-φIs 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 mesh2l) And samples (S) smaller than 80 mesh2s). 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 EPackage body)。
Extracting the reservoir asphalt (E) in the obtained oil-bearing rock sampleLeaching) 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:
MPIasphalt＝1.5×[3-MPAsphalt+2-MPAsphalt]/[PAsphalt+9-MPAsphalt+1-MPAsphalt]) Formula (3)
MPIIs movable＝1.5×[3-MPIs movable+2-MPIs movable]/[PIs movable+9-MPIs movable+1-MPIs movable]) Formula (4)
MPIPackage body＝1.5×[3-MPPackage body+2-MPPackage body]/[PPackage body+9-MPPackage body+1-MPPackage 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 MPIAsphaltMethyl phenanthrene refers to asphaltNumber, MPIIs movableRefers to the methyl phenanthrene index, MPI, of the mobile oilPackage bodyThe index refers to the phenanthrene index of a reservoir inclusion oil; MP (moving Picture experts group)AsphaltMethyl phenanthrene, MP, being pitchIs movableMethyl phenanthrene, MP as a mobile oilPackage bodyMethylphenanthrene, P, being a reservoir inclusion oilAsphaltIs the phenanthrene content of the bitumen, PIs movableIs the phenanthrene content of the mobile oil, PPackage bodyIs 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 RmAsphalt＝0.6×MPILeaching+0.4 equation (6)
Calculating maturity Rm of mobile oilIs movable＝0.6×MPIIs movable+0.4 equation (7)
Calculating the maturity Rm of the inclusionPackage body＝0.6×MPIIs 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 mapAsphaltMovable oil filling geological time TIs movableAnd capturing geological period T of oil-containing inclusionPackage 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):
(φis movableI.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:
(φgeneral assemblyI.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:
φasphalt＝φGeneral assembly-φIs 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 mesh2l) And samples (S) smaller than 80 mesh2s). 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 EPackage 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 sampleAsphalt) 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:
MPIasphalt＝1.5×[3-MP+2-MP]/[P+9-MP+1-MP])
＝1.5×[222+550]/[1495+611+486])＝0.45
MPIIs movable＝1.5×[3-MP+2-MP]/[P+9-MP+1-MP])
＝1.5×[1472+2024]/[2716+2066+1488])＝0.84
MPIPackage 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: rmAsphalt＝0.6×MPILeaching+0.4＝0.6× 0.45+0.4＝0.67
Mobile oil calculated maturity: rmIs movable＝0.6×MPIIs movable+0.4＝0.6× 0.84+0.4＝0.90
And (3) calculating the maturity of the inclusion: rmPackage body＝0.6×MPIIs 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 TLeachingIn the geological period T of 190Ma, namely early-middle Jurassic and mobile oil fillingIs movableAt 140Ma, early chalkiness, geological time T for trapping oil-containing inclusionsPackage bodyAs 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 periodMovable (%)7.58％，φAsphalt (%)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.
Claims (9)
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:
φis movableI.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:
φgeneral assemblyThe 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:
φleaching＝φGeneral assembly-φIs 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 mesh2lAnd sample S of less than 80 mesh2sRespectively extracting two samples;
step 32, for the sample S larger than 80 meshes2lWith 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 rockLeaching；
Step 33, for sample S smaller than 80 meshes2sWith 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 rockIs 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 rockPackage 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 extractedLeachingMovable oil EIs movableReservoir inclusion oil EPackage bodySeparating 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:
MPIasphalt＝1.5×[3-MPAsphalt+2-MPAsphalt]/[PAsphalt+9-MPAsphalt+1-MPAsphalt]) Formula (3)
MPIIs movable＝1.5×[3-MPIs movable+2-MPIs movable]/[PIs movable+9-MPIs movable+1-MPIs movable]) Formula (4)
MPIPackage body＝1.5×[3-MPPackage body+2-MPPackage body]/[PPackage body+9-MPPackage body+1-MPPackage body]) Formula (5)
MPIAsphaltRefers to the Meffy index, MPI, of the asphaltIs movableRefers to the methyl phenanthrene index, MPI, of the mobile oilPackage bodyThe index refers to the phenanthrene index of a reservoir inclusion oil; MP (moving Picture experts group)AsphaltMethyl phenanthrene, MP, being pitchIs movableMethyl phenanthrene, MP as a mobile oilPackage bodyMethylphenanthrene, P, being a reservoir inclusion oilAsphaltIs the phenanthrene content of the bitumen, PIs movableIs the phenanthrene content of the mobile oil, PPackage bodyFor 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 RmAsphalt＝0.6×MPILeaching+0.4 equation (6)
Calculating maturity Rm of mobile oilIs movable＝0.6×MPIIs movable+0.4 equation (7)
Calculating the maturity Rm of the inclusionPackage body＝0.6×MPIIs 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 obtainedAsphaltMovable oil filling geological time TIs movableAnd capturing geological period T of oil-containing inclusionPackage body。
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