CN110836112A - Method for determining oil deposit formation time and period - Google Patents
Method for determining oil deposit formation time and period Download PDFInfo
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- CN110836112A CN110836112A CN201911217469.XA CN201911217469A CN110836112A CN 110836112 A CN110836112 A CN 110836112A CN 201911217469 A CN201911217469 A CN 201911217469A CN 110836112 A CN110836112 A CN 110836112A
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- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 73
- 238000000034 method Methods 0.000 title claims abstract description 50
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 98
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 98
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 98
- 229910052900 illite Inorganic materials 0.000 claims abstract description 38
- VGIBGUSAECPPNB-UHFFFAOYSA-L nonaaluminum;magnesium;tripotassium;1,3-dioxido-2,4,5-trioxa-1,3-disilabicyclo[1.1.1]pentane;iron(2+);oxygen(2-);fluoride;hydroxide Chemical compound [OH-].[O-2].[O-2].[O-2].[O-2].[O-2].[F-].[Mg+2].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[K+].[K+].[K+].[Fe+2].O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2 VGIBGUSAECPPNB-UHFFFAOYSA-L 0.000 claims abstract description 38
- 239000011435 rock Substances 0.000 claims abstract description 38
- 238000004088 simulation Methods 0.000 claims abstract description 14
- 238000009933 burial Methods 0.000 claims abstract description 10
- 238000004458 analytical method Methods 0.000 claims abstract description 6
- 238000005070 sampling Methods 0.000 claims description 11
- 238000010438 heat treatment Methods 0.000 claims description 7
- 238000001816 cooling Methods 0.000 claims description 3
- 238000011160 research Methods 0.000 claims description 2
- 238000005259 measurement Methods 0.000 description 16
- 229910052586 apatite Inorganic materials 0.000 description 5
- 230000004992 fission Effects 0.000 description 5
- VSIIXMUUUJUKCM-UHFFFAOYSA-D pentacalcium;fluoride;triphosphate Chemical compound [F-].[Ca+2].[Ca+2].[Ca+2].[Ca+2].[Ca+2].[O-]P([O-])([O-])=O.[O-]P([O-])([O-])=O.[O-]P([O-])([O-])=O VSIIXMUUUJUKCM-UHFFFAOYSA-D 0.000 description 5
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000012360 testing method Methods 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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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V9/00—Prospecting or detecting by methods not provided for in groups G01V1/00 - G01V8/00
- G01V9/005—Prospecting or detecting by methods not provided for in groups G01V1/00 - G01V8/00 by thermal methods, e.g. after generation of heat by chemical reactions
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Abstract
The invention discloses a method for determining the formation time and the period of an oil reservoir, which comprises the following steps: recovering the burial history and the temperature evolution history of the basin by adopting a basin thermal evolution history analysis method, according to an ancient temperature scale method and by combining basin simulation software, determining the hydrocarbon generation starting temperature, a large amount of hydrocarbon discharge temperature and the complete maturity temperature of the hydrocarbon source rock according to the hydrocarbon generation and discharge simulation by adopting a hydrocarbon source rock hydrocarbon generation and discharge method, determining the K-Ar age in the self-generated illite in a reservoir by adopting a self-generated illite dating method, extracting the thermal evolution history information of the layer where an oil layer is located from S1, and calibrating the parameters of the hydrocarbon generation temperature, the large amount of hydrocarbon discharge temperature and the complete maturity temperature of the hydrocarbon source rock obtained from S2 in the thermal evolution history information in S4. The method avoids the situation that in the basin simulation method, the time after the thermal evolution degree is higher, the thermal event or the thermal event is continuously heated but is less than the highest temperature reached by the early thermal event, but the hydrocarbon generation is stopped is taken as the period of reservoir formation.
Description
Technical Field
The invention relates to the technical field of oil reservoir exploration, in particular to a method for determining oil reservoir formation time and phase.
Background
The formation period of the oil deposit is a very key problem in the geological evaluation link of oil deposit exploration. At present, the research methods of the formation time-phase times of the oil reservoir mainly comprise a tectonic evolution analysis method, a trap formation method, an authigenic illite dating method, a hydrocarbon source rock hydrocarbon generation and expulsion method, an inclusion homogeneous temperature method and a basin thermal evolution history analysis method. However, the existing single method cannot accurately obtain the geological parameters of the oil deposit reservoir and accurately determine the period and the phase of the oil deposit reservoir, so that the method for determining the formation time and the phase of the oil deposit is provided.
Disclosure of Invention
Based on the technical problems in the background art, the invention provides a method for determining the formation time and the period of an oil reservoir.
The invention provides a method for determining the formation time and the period of an oil reservoir, which comprises the following steps:
s1: recovering the burial history and the temperature evolution history of the basin by adopting a basin thermal evolution history analysis method and combining basin simulation software according to an ancient earth temperature scale method;
s2: determining the hydrocarbon generation starting temperature, the large-amount hydrocarbon discharge temperature and the complete maturity temperature of the hydrocarbon source rock according to the hydrocarbon generation and discharge simulation by adopting a hydrocarbon source rock hydrocarbon generation and discharge method;
s3: determining the age of K-Ar in the authigenic illite in the reservoir by adopting an authigenic illite dating method;
s4: extracting thermal evolution history information of the layer position of the oil layer from S1;
s5: calibrating the parameters of the hydrocarbon generation temperature, the mass hydrocarbon discharge temperature and the complete maturity temperature of the source rock obtained in the step S2 in the thermal evolution history information in the step S4;
s6: determining the starting time of the first-stage reservoir formation;
s7: marking the formation start time of the first-stage oil deposit in the thermal evolution history chart extracted in the S4, and taking continuous temperature rise as an interval until the temperature rise stops or is reduced, so that the first-stage reservoir formation is finished;
s8: the starting time of the next period is from the time of reaching the peak value of the previous temperature to the time of stopping heating or cooling at the present period;
s9: and repeating S8 until the hydrocarbon source rock is over mature and is not regenerated to discharge hydrocarbon or the historical period evolves to the present day.
Preferably, the Basin simulation software employs the Basin Model and the thermal history simulation method employs the EASY% Ro method.
Preferably, the sample in S1 is taken to be the layer of interest.
Preferably, the ancient ground temperature scale method adopts maturity temperature, inclusion temperature scale or thermal history simulation temperature scale.
Preferably, the first phase reservoir formation begins at the same age as the latest K-Ar age of the finest authigenic illite in the reservoir.
Preferably, in S7, if the temperature is continuously increased from the first stage of reservoir formation to the present day, the reservoir is at the maximum burial depth and the present formation temperature is the highest temperature under the present temperature condition, and the hydrocarbon source rock is not completely over-mature, the reservoir formation time is determined as a stage from the age of yianite K-Ar to the present day, and S8 and S9 are skipped.
Preferably, in S7, if the temperature is continuously increased from the first stage of reservoir formation until the present day, under the present temperature condition, the reservoir is at the maximum burial depth and the present formation temperature is the highest temperature, the hydrocarbon source rock is over-mature, the reservoir formation time is determined as a first stage, from the age of the illite K-Ar, to the time when the hydrocarbon source rock reaches the over-mature temperature, and S8 and S9 are skipped.
The beneficial effects of the invention are as follows:
1. the method avoids the time for starting hydrocarbon generation by mistake as the time for starting reservoir formation, takes the measured years of illite as the time for starting reservoir filling and reservoir formation, avoids the delay between hydrocarbon generation and filling in the hydrocarbon generation simulation method, more intuitively reflects the starting time of the next-stage reservoir formation by establishing a new chart, avoids the period for bringing the thermal event lower than the maximum temperature of the previous-stage reservoir into the reservoir formation in the basin simulation method, and avoids the period for taking the time after the hydrocarbon generation is stopped as the period for reservoir formation, wherein the thermal event has higher thermal evolution degree and is or is continuously heated but is lower than the maximum temperature reached by the previous-stage thermal event.
2. And (3) making up for the shortages, adopting the determined and reasonable reservoir formation time part in each method, omitting errors possibly caused by the entrance and exit of the application premise of the method and the actual evolution history, and finally obtaining the starting time and the ending time of the formation of the oil reservoir according to accurate parameter analysis, so that the errors can be effectively eliminated, and the result is more accurate.
3. The three conditions of stopping temperature rise, over-maturing the hydrocarbon source rock and reaching the present time are definitely used as the conditions or the cut-off conditions for stopping oil deposit generation, and errors can be avoided.
Drawings
FIG. 1 is a basin burial history and evolution history chart of a method for determining the formation time and duration of an oil reservoir according to the invention;
FIG. 2 is a plot of the temperature evolution history of the reservoir organized according to FIG. 1 for a method of determining the time and duration of reservoir formation according to the present invention;
FIG. 3 is a plot of the reservoir evolution history with hydrocarbon generation parameters for a method of determining the time and duration of reservoir formation according to the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments.
Example 1, a method of determining the time and duration of reservoir formation comprising the steps of:
sampling a target oil layer, and measuring an apatite fission track;
simulating the basin buried history and the thermal evolution history by adopting Base Model software according to the measurement result;
drawing a buried history and a thermal evolution history map of a basin where an oil layer is located;
extracting a thermal evolution history chart of the oil layer;
carrying out illite K-Ar year measurement on an oil-bearing reservoir, recording parameters, and stopping the formation of the authigenic illite when the reservoir is filled into the reservoir, so that the latest K-Ar age of the finest authigenic illite in the reservoir is measured, wherein the age is the time for the illite to stop growing;
sampling immature hydrocarbon source rocks of an oil layer group where the basin is located, carrying out hydrocarbon generation simulation, and recording hydrocarbon generation starting temperature and hydrocarbon generation stopping temperature of the hydrocarbon source rocks;
marking the hydrocarbon generation starting temperature, the hydrocarbon generation stopping temperature, the latest age of the illite K-Ar year measurement and the time when the next thermal evolution temperature exceeds the highest temperature of the previous time on an oil layer temperature evolution history map to form a new plate;
marking the formation starting time of the first-stage oil deposit in the evolution history chart, and taking continuous temperature rise (generation and discharge of hydrocarbon) as an interval until the temperature rise stops, so that the first-stage oil deposit formation is finished;
starting time of the next period is from reaching the time of the previous temperature peak to stopping heating at the current period, and repeating until the hydrocarbon source rock is over mature and is not regenerated to discharge hydrocarbon or the historical period evolves to the present;
and recording the period of reservoir formation.
Example 2, a method of determining the time and duration of reservoir formation comprising the steps of:
sampling a target oil layer, and measuring an apatite fission track;
simulating the basin buried history and the thermal evolution history by adopting Base Model software according to the measurement result;
drawing a buried history and a thermal evolution history map of a basin where an oil layer is located;
extracting a thermal evolution history chart of the oil layer;
carrying out illite K-Ar year measurement on an oil-bearing reservoir, recording parameters, and stopping the formation of the authigenic illite when the reservoir is filled into the reservoir, so that the latest K-Ar age of the finest authigenic illite in the reservoir is measured, wherein the age is the time for the illite to stop growing;
sampling immature hydrocarbon source rocks of an oil layer group where the basin is located, carrying out hydrocarbon generation simulation, and recording hydrocarbon generation starting temperature and hydrocarbon generation stopping temperature of the hydrocarbon source rocks;
marking the hydrocarbon generation starting temperature, the hydrocarbon generation stopping temperature, the latest age of the illite K-Ar year measurement and the time when the next thermal evolution temperature exceeds the highest temperature of the previous time on an oil layer temperature evolution history map to form a new plate;
marking the formation starting time of the first-stage oil deposit in the evolution history chart, taking continuous temperature rise (generation and discharge of hydrocarbon) as an interval until temperature drop is reached, and ending the first-stage oil deposit formation;
the starting time of the next period is repeated from the time of reaching the previous temperature peak value until the current period is cooled, until the hydrocarbon source rock is over-mature and is not regenerated to discharge hydrocarbon or the historical period evolves to the present;
and recording the period of reservoir formation.
Example 3, a method of determining the time and duration of reservoir formation comprising the steps of:
sampling a target oil layer, and measuring an apatite fission track;
simulating the basin buried history and the thermal evolution history by adopting Base Model software according to the measurement result;
drawing a buried history and a thermal evolution history map of a basin where an oil layer is located;
extracting a thermal evolution history chart of the oil layer;
carrying out illite K-Ar year measurement on an oil-bearing reservoir, recording parameters, and stopping the formation of the authigenic illite when the reservoir is filled into the reservoir, so that the latest K-Ar age of the finest authigenic illite in the reservoir is measured, wherein the age is the time for the illite to stop growing;
sampling immature hydrocarbon source rocks of an oil layer group where the basin is located, carrying out hydrocarbon generation simulation, and recording hydrocarbon generation starting temperature and hydrocarbon generation stopping temperature of the hydrocarbon source rocks;
marking the hydrocarbon generation starting temperature, the hydrocarbon generation stopping temperature, the latest age of the illite K-Ar year measurement and the time when the next thermal evolution temperature exceeds the highest temperature of the previous time on an oil layer temperature evolution history map to form a new plate;
marking the formation starting time of a first-stage oil deposit in an evolution history chart, taking continuous temperature rise (generation and discharge of hydrocarbon) as an interval, continuously raising the temperature until the oil deposit is in the first stage when the reservoir is at the maximum burial depth and the formation temperature is the highest temperature and the hydrocarbon source rock is not completely over-mature at present under the current temperature condition, and determining the formation time of the oil deposit as the first stage from the age of the illite K-Ar to the end of the first stage;
and recording the period of reservoir formation.
Example 4, a method of determining the time and duration of reservoir formation comprising the steps of:
sampling a target oil layer, and measuring an apatite fission track;
simulating the basin buried history and the thermal evolution history by adopting Base Model software according to the measurement result;
drawing a buried history and a thermal evolution history map of a basin where an oil layer is located;
extracting a thermal evolution history chart of the oil layer;
carrying out illite K-Ar year measurement on an oil-bearing reservoir, recording parameters, and stopping the formation of the authigenic illite when the reservoir is filled into the reservoir, so that the latest K-Ar age of the finest authigenic illite in the reservoir is measured, wherein the age is the time for the illite to stop growing;
sampling immature hydrocarbon source rocks of an oil layer group where the basin is located, carrying out hydrocarbon generation simulation, and recording hydrocarbon generation starting temperature and hydrocarbon generation stopping temperature of the hydrocarbon source rocks;
marking the hydrocarbon generation starting temperature, the hydrocarbon generation stopping temperature, the latest age of the illite K-Ar year measurement and the time when the next thermal evolution temperature exceeds the highest temperature of the previous time on an oil layer temperature evolution history map to form a new plate;
marking the formation starting time of a first-stage oil deposit in an evolution history chart, taking continuous temperature rise (generation and discharge of hydrocarbon) as an interval, continuously raising the temperature until the current temperature is reached, wherein under the current temperature condition, the reservoir is at the maximum burial depth and the current stratum temperature is the highest temperature, the hydrocarbon source rock is over-mature, and determining the formation time of the oil deposit as a first stage until the hydrocarbon source rock reaches the over-mature temperature from the age of the generation illite K-Ar;
and recording the period of reservoir formation.
Example 5, a method of determining the time and duration of reservoir formation comprising the steps of:
sampling a basin oil layer in a certain oil area, and measuring an apatite fission track;
simulating the basin buried history and the thermal evolution history by adopting Base Model software according to the measurement result;
referring to fig. 1, a buried history and a thermal evolution history map of a basin where an oil layer is located are drawn;
referring to fig. 2, extracting a thermal evolution history map of an oil layer;
carrying out illite K-Ar year measurement on an oil-bearing reservoir, recording parameters, carrying out illite K-Ar year measurement on the oil-bearing reservoir, recording the parameters, entering the reservoir according to the oil deposit filling, and stopping the formation of the authigenic illites, so that the latest K-Ar age of the finest authigenic illites in the reservoir is measured, wherein the age is the time for the illite to stop growing;
sampling immature hydrocarbon source rocks of an oil layer group where the basin is located, carrying out hydrocarbon generation simulation, and recording hydrocarbon generation starting temperature and hydrocarbon generation stopping temperature of the hydrocarbon source rocks;
referring to fig. 3, marking the hydrocarbon generation starting temperature, the hydrocarbon generation stopping temperature, the latest age of illite K-Ar measurement and the time when the next thermal evolution temperature exceeds the previous highest temperature on the thermal evolution history map of the oil layer to form a new plate;
marking the formation starting time of the first-stage oil deposit in the evolution history chart, and taking continuous temperature rise (generation and discharge of hydrocarbon) as an interval until the temperature rise stops or is reduced, so that the first-stage reservoir formation is finished;
starting time of the next period is from reaching the time of the previous temperature peak to stopping heating or cooling at the current period, and repeating until the hydrocarbon source rock is over mature and is not regenerated to discharge hydrocarbon or the historical period evolves to the present;
recording the period of reservoir formation;
the time interval for finally obtaining the reservoir formation of the oil reservoir layer is as follows:
obtaining the hydrocarbon starting time of the source rock as 62 ℃ according to the hydrocarbon generation simulation, wherein the corresponding time is-271 Ma;
obtaining authigenic illite at-261 Ma by illite K-Ar test, so that the reservoir begins filling after 10Ma authigenic hydrocarbon, so that the first phase reservoir formation time starts at-261 Ma and ends when the first thermal event or the first-247 Ma stops heating, and the first phase reservoir formation time is (-261-;
the time when the second heat history exceeds the first peak temperature is-155 Ma, the time for stopping heating is-97 Ma, so the time for the second-phase oil deposit to be formed is-155-97 Ma;
although 42Ma has a new thermal history event or heating process, the highest temperature of the previous time is not exceeded until the current hydrocarbon source rock does not evolve to an over-mature stage in which hydrocarbon generation stops, so that a third-stage reservoir formation event does not occur in the oil layer;
and (4) conclusion: the hydrocarbon generation time of the hydrocarbon source rock in the oil zone is started from-271 Ma, hydrocarbon is discharged after 10Ma and is filled into a reservoir, and the composition of the oil reservoir in the zone is divided into two phases: the first phase of filling occurs at-261-247) Ma and the second phase at-155-97) Ma.
The mechanism of the gas reservoir and the mechanism of the oil reservoir are the same, so the period of the gas reservoir can be analyzed and determined according to the method.
The above description is only for the preferred embodiment of the present invention, but the scope of the present invention is not limited thereto, and any person skilled in the art should be considered to be within the technical scope of the present invention, and the technical solutions and the inventive concepts thereof according to the present invention should be equivalent or changed within the scope of the present invention.
Claims (7)
1. A method of determining the time and duration of reservoir formation comprising the steps of:
s0: sampling in a target oil layer to obtain a sample;
s1: recovering the burial history and the temperature evolution history of the basin by adopting a basin thermal evolution history analysis method and combining basin simulation software according to an ancient earth temperature scale method;
s2: determining the hydrocarbon generation starting temperature, the large-amount hydrocarbon discharge temperature and the complete maturity temperature of the hydrocarbon source rock according to the hydrocarbon generation and discharge simulation by adopting a hydrocarbon source rock hydrocarbon generation and discharge method;
s3: determining the age of K-Ar in the authigenic illite in the reservoir by adopting an authigenic illite dating method;
s4: extracting thermal evolution history information of the layer position of the oil layer from S1;
s5: calibrating the parameters of the hydrocarbon generation temperature, the mass hydrocarbon discharge temperature and the complete maturity temperature of the source rock obtained in the step S2 in the thermal evolution history information in the step S4;
s6: determining the starting time of the first-stage reservoir formation;
s7: marking the formation start time of the first-stage oil deposit in the thermal evolution history chart extracted in the S4, and taking continuous temperature rise as an interval until the temperature rise stops or is reduced, so that the first-stage reservoir formation is finished;
s8: the starting time of the next period is from the time of reaching the peak value of the previous temperature to the time of stopping heating or cooling at the present period;
s9: and repeating S8 until the hydrocarbon source rock is over mature and is not regenerated to discharge hydrocarbon or the historical period evolves to the present day.
2. The method of claim 1, wherein the Basin modeling software uses Basin Model and the thermal history modeling method uses EASY% Ro.
3. The method for determining the time and duration of reservoir formation according to claim 1, wherein the sample in S1 is a research target horizon.
4. The method of claim 1, wherein the paleogeothermometry method uses maturity temperature, inclusion temperature scale, or thermal history simulated temperature scale.
5. The method of determining the time and number of stages in a reservoir of claim 1, wherein the first stage reservoir formation begins at the same time as the latest K-Ar age of the finest authigenic illites in the reservoir.
6. The method of claim 1, wherein in step S7, if the temperature is continuously increased from the first stage of reservoir formation to the present day, the reservoir is at the maximum burial depth and the present formation temperature is the highest temperature under the present temperature condition, and the source rock is not completely over-mature, the reservoir formation time is determined as one stage from the age of yield K-Ar to the present day, and S8 and S9 are skipped.
7. The method of claim 1, wherein in step S7, if the temperature is continuously increased from the first stage of reservoir formation to the present day, the reservoir is at the maximum burial depth and the present formation temperature is the highest temperature under the present day temperature condition, the source rock is over-mature, the reservoir formation time is determined as one stage, starting from the age of yield K-Ar, ending with the time when the source rock reaches the over-mature temperature, and skipping S8 and S9.
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