CN112814655A - Method for correcting saturation of bound water of shale gas reservoir - Google Patents
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Abstract
The invention discloses a method for correcting saturation of bound water of a shale gas reservoir, which solves the problem of large error of saturation of bound water of the existing shale gas reservoir. The technical scheme comprises the following steps: 1) acquiring total porosity POR of shale gas reservoir and water saturation S of shale gas reservoir of well to be correctedwThe measurement unit is%; 2) calculating organic porosity POR of shale gas reservoir at corresponding pointTOCThe measurement unit is%; 3) utilizing total porosity POR of shale gas reservoir and water saturation S of shale gas reservoirwPOR of organic porosity of shale gas reservoirTOCAccording to a model Swi＝(POR‑PORTOC)/POR·SwCalculating the shale gas reservoir bound water of the well to be correctedSaturation SwiThe measurement unit is%; 4) and outputting a final correction result. The method is extremely simple, suitable for the shale gas reservoir, high in accuracy and good in adaptability.
Description
Technical Field
The invention relates to the field of logging of shale gas, in particular to a method for correcting saturation of bound water of a shale gas reservoir.
Background
In the quantitative evaluation and comprehensive evaluation process of the shale gas reservoir, the saturation parameter of the shale gas reservoir irreducible water is usually used, and the saturation of the irreducible water is combined with other reservoir key parameters to realize the multi-parameter quantitative evaluation and comprehensive interpretation, and one of the important key parameters of the shale gas reservoir interpretation evaluation. In the shale gas reservoir, because the permeability is extremely low, the horizontal bedding permeability and the vertical permeability are close to 0md, so that the contained water is represented as bound water, no movable water exists, and the water saturation at the moment is the shale gas reservoir bound water saturation.
For a conventional oil and gas reservoir, based on the consideration of oil and gas migration, when oil and gas are transported from a crude oil rock to a sandstone reservoir, due to the wettability difference of oil, water and gas on the rock and the action of capillary force, the oil and gas migrated under the action of buoyancy cannot completely displace water in the sandstone reservoir, and a certain amount of water remains in pores of the reservoir. The water exists in the corners and fine pores where the rock particles contact or is adsorbed on the surface of the rock skeleton particles. Due to the particular distribution and presence pattern, this portion of water is almost non-mobile and is therefore called immobile water, also called residual water or irreducible water, and the corresponding water saturation is called irreducible water saturation.
The shale gas reservoir irreducible water saturation is one of important parameters for measuring the quality of the shale gas reservoir, and can provide explanation key parameters for quantitative characterization and comprehensive evaluation of shale gas reservoir characteristics. The conventional calculation of the water saturation of the shale gas reservoir is to calculate the obtained water saturation by adopting formulas such as Archie and the like, and scholars also calculate the water saturation by using f (POR, Vsh) functions, wherein POR is the total porosity of the shale gas reservoir, and Vsh is the shale content of the shale gas reservoir. Researchers find that the shale gas reservoir irreducible water saturation obtained by the method has the problem of large error in practical application;
CN106324688A discloses a reservoir irreducible water saturation determination method and a device thereof, and provides a reservoir irreducible water saturation determination method and a device thereof. The method is characterized in that: and performing integral transformation on the acquired nuclear magnetic resonance echo data according to the updated exponential hyperbolic sine function to determine the reservoir bound water saturation, so that uncertainty caused by inversion can be avoided, and the accurate reservoir bound water saturation can be obtained under the condition of low signal-to-noise ratio of the nuclear magnetic resonance echo data. The disclosed technology is suitable for a conventional oil and gas reservoir, and when the method is used for measuring and calculating the saturation information of the bound water of the shale gas reservoir, the shale gas reservoir has the characteristic of taking nano-to micron-sized organic pores as the main pore conditions, so that the error is larger, and the method is not suitable for the shale gas reservoir with special geological conditions. Therefore, a new method is needed to solve the problem of measuring and correcting the saturation of the irreducible water in the shale gas reservoir.
Disclosure of Invention
The invention aims to solve the technical problems and provides a method for correcting the saturation of the bound water in the shale gas reservoir, which is extremely simple, suitable for the shale gas reservoir, high in accuracy and good in adaptability.
The technical scheme comprises the following steps:
1) acquiring total porosity POR of shale gas reservoir and water saturation S of shale gas reservoir of well to be correctedw(i.e., shale gas reservoir irreducible water saturation) in;
2) calculating organic porosity POR of shale gas reservoir at corresponding pointTOCThe measurement unit is%;
3) utilizing total porosity POR of shale gas reservoir and water saturation S of shale gas reservoirwPOR of organic porosity of shale gas reservoirTOCAccording to a model Swi＝(POR-PORTOC)/POR·SwCalculating the saturation S of the shale gas reservoir irreducible water of the well to be correctedwiThe measurement unit is%;
4) and outputting a final correction result.
Wherein in the step 2), the shale gas reservoir organic porosity PORTOCThe calculation method comprises the following steps:
a) acquiring apparent organic matter conversion efficiency eta of a shale gas reservoir in a work area;
b) acquiring acoustic time difference AC and density DEN logging information of a shale gas reservoir to be predicted;
c) calculating the acoustic time difference logging porosity POR of the corresponding depth point by using the acoustic time difference AC logging data of the shale gas reservoir to be predicted in the step b)AC；
d) Calculating the total organic carbon content TOC of the corresponding depth point by using the density DEN logging information of the point to be predicted of the well shale gas reservoir in the step b)DEN(ii) a Or Total Organic Carbon (TOC) content of shale gas reservoir measured by logging geochemical methodDEN；
e) Obtaining total organic carbon content TOC by utilizing apparent organic matter conversion efficiency eta of shale gas reservoir and step d)DENAnd c) solving the acoustic time difference logging porosity PORACData according to model PORTOC＝η·TOCDEN·PORACCalculating the shale gas reservoir organic porosity POR of the well to be predictedTOC；
In the step a), the apparent organic matter conversion efficiency eta of the shale gas reservoir is obtained by adopting the following method:
a1) obtaining shale gas reservoir organic porosity POR obtained by laboratory analysis of coring well in work areaTOC1；
a2) Calculating acoustic time difference logging porosity POR of corresponding depth point by using acoustic time difference logging data of shale gas reservoirAC1；
The calculation formula is PORAC1＝A1·AC－B1，
In the formula of PORAC1 is the acoustic moveout logging porosity, in units,
wherein AC is a sonic logging value of a corresponding depth point, A1 and B1 are area scale coefficients of the AC, A1 is 0.0621 in Fuling area, and B1 is 11.089;
a3) calculating the total organic carbon content TOCDEN1 of the corresponding depth point by using the density DEN data of the shale gas reservoir;
the formula is TOCDEN1 ═ M1 · (N1-DEN),
wherein TOCDEN1 is the total organic carbon content,
DEN is the density log of the corresponding depth point, in g/cm3,
m1 and N1 are DEN zone scale coefficients, such as M1-20.0 and N1-2.71 in the Fuling zone.
Or the total organic carbon content of the shale gas reservoir measured by a logging geochemical method is used for replacing TOCDEN1；
a4) Calculating organic porosity ratio value POR of shale gas reservoir corresponding to each pointTOC1/PORAC1, TOC corresponding to each pointDEN1, modeling POR by least squaresTOC1/PORAC1＝η·TOCDENAnd 1, determining apparent organic matter conversion efficiency eta of the shale gas reservoir, wherein eta is generally expressed by decimal.
In view of the problems in the background art, the inventors have conducted intensive studies to find that, in the shale gas reservoir, the bound water is also present in the corners and the fine pores of the rock particle contact part, or adsorbed on the surface of the rock skeleton particle, and is represented as immobile water. In other words, the bound water in the shale gas reservoir is also present in the inorganic pores of the shale gas reservoir, the mobile water and the bound water are not present in the organic pores, and the organic matter evolves to consume the bound water around the organic pores during the formation of the shale organic pores, so that enough gas storage space is provided for the shale gas generated by self-storage. After the shale gas meets the self adsorption of the formation conditions, the surplus shale gas is stored in the inorganic pores and the organic pores of the shale and can be transported in the inorganic pores of the shale for a short distance. With the increase of the content of the surplus shale gas in the reservoir, the expansion causes the closed shale reservoir to show abnormal high pressure, the bound water in the shale is continuously consumed, the flow cannot occur, and the bound water cannot enter organic pores from inorganic pores in the shale, so the gas saturation in the organic pores is always 100%.
However, the irreducible water saturation measuring method determined by the traditional method cannot determine organic pores with the pore diameters ranging from nanometer to micron in the shale gas reservoir, the obtained irreducible water saturation of the shale gas reservoir is substantially reflected by the irreducible water saturation of the shale gas reservoir in the inorganic pores of the shale gas reservoir and is regarded as the irreducible water saturation representing the whole pore space of the shale gas reservoir, the existence of water in the shale gas reservoir is amplified invisibly, the irreducible water saturation value in the inorganic pores of the shale gas reservoir is reduced, the objective fact that water is not contained in the organic pores of the shale gas reservoir is blurred, the shale gas reservoir irreducible water saturation quantization representing error is large, and an accurate expression value needs to be obtained through correction.
The method is based on the new invention and the objective error problem, the correction method is provided, the technical problem that the water saturation of the shale gas reservoir in the logging site cannot reflect the real bound water saturation of the shale gas reservoir is solved through the method, and the method is simple and convenient, low in cost and high in applicability.
Drawings
FIG. 1 is a block diagram of the workflow of the present invention;
Detailed Description
Referring to fig. 1, the present invention comprises the steps of:
1) acquiring total porosity POR of shale gas reservoir and water saturation S of shale gas reservoir of well to be correctedwThe shale gas reservoir irreducible water saturation, and the measurement unit is% (volume percentage);
2) calculating organic porosity POR of shale gas reservoir at corresponding pointTOCThe measurement unit is%; the shale gas reservoir organic porosity PORTOCThe method described in publication No. CN107247860B or other feasible organic porosity calculation methods are preferably used, and specifically, as a preferred example:
a) acquiring apparent organic matter conversion efficiency eta of a shale gas reservoir in a work area;
the apparent organic matter conversion efficiency eta of the shale gas reservoir is obtained by adopting the following method:
a1) obtaining shale gas reservoir organic porosity POR obtained by laboratory analysis of coring well in work areaTOC1；
a2) Calculating acoustic time difference logging porosity POR of corresponding depth point by using acoustic time difference logging data of shale gas reservoirAC1；
The calculation formula is PORAC1＝A1·AC－B1，
In the formula of PORAC1 is the acoustic moveout porosity, in% (volume percent),
wherein AC is a sonic logging value of a corresponding depth point, A1 and B1 are area scale coefficients of the AC, A1 is 0.0621 in Fuling area, and B1 is 11.089;
a3) calculating the total organic carbon content TOCDEN1 of the corresponding depth point by using the density DEN data of the shale gas reservoir;
the formula is TOCDEN1 ═ M1 · (N1-DEN),
wherein TOCDEN1 is the total organic carbon content,
DEN is the density log of the corresponding depth point, in g/cm3,
m1 and N1 are DEN zone scale coefficients, such as M1-20.0 and N1-2.71 in the Fuling zone.
Or the total organic carbon content of the shale gas reservoir measured by a logging geochemical method is used for replacing TOCDEN1；
a4) Calculating organic porosity ratio value POR of shale gas reservoir corresponding to each pointTOC1/PORAC1, TOC corresponding to each pointDEN1, modeling POR by least squaresTOC1/PORAC1＝η·TOCDENAnd 1, determining apparent organic matter conversion efficiency eta of the shale gas reservoir, wherein eta is generally expressed by decimal.
b) Acquiring acoustic time difference AC and density DEN logging information of a shale gas reservoir to be predicted;
c) using the acoustic wave of the well shale gas reservoir to be predicted in step b)Calculating acoustic time difference logging porosity POR of corresponding depth point by using differential AC logging dataAC；
d) Calculating the total organic carbon content TOC of the corresponding depth point by using the density DEN logging information of the point to be predicted of the well shale gas reservoir in the step b)DEN(ii) a Or Total Organic Carbon (TOC) content of shale gas reservoir measured by logging geochemical methodDEN；
e) Obtaining total organic carbon content TOC by utilizing apparent organic matter conversion efficiency eta of shale gas reservoir and step d)DENAnd c) solving the acoustic time difference logging porosity PORACData according to model PORTOC＝η·TOCDEN·PORACCalculating the shale gas reservoir organic porosity POR of the well to be predictedTOC；
3) Utilizing total porosity POR of shale gas reservoir and water saturation S of shale gas reservoirwPOR of organic porosity of shale gas reservoirTOCAccording to a model Swi＝(POR-PORTOC)/POR·SwCalculating the saturation S of the shale gas reservoir irreducible water of the well to be correctedwiMeasured in% (volume percent);
4) and outputting a final correction result.
The invention has applied more than 200 wells in the Fuling shale gas field, can meet the requirement of field logging interpretation work, and improves the field shale gas reservoir interpretation evaluation precision.
Claims (3)
1. A method for correcting irreducible water saturation of a shale gas reservoir is characterized by comprising the following steps:
1) acquiring total porosity POR of shale gas reservoir and water saturation S of shale gas reservoir of well to be correctedwThe measurement unit is%;
2) calculating organic porosity POR of shale gas reservoir at corresponding pointTOCThe measurement unit is%;
3) utilizing total porosity POR of shale gas reservoir and water saturation S of shale gas reservoirwPOR of organic porosity of shale gas reservoirTOCAccording to a model Swi＝(POR-PORTOC)/POR·SwTo calculateCorrecting shale gas reservoir irreducible water saturation S of wellwiThe measurement unit is%;
4) and outputting a final correction result.
2. The method for correcting the irreducible water saturation of the shale gas reservoir as claimed in claim 1, wherein in the step 2), the shale gas reservoir organic porosity POR is adoptedTOCThe calculation method comprises the following steps:
a) acquiring apparent organic matter conversion efficiency eta of a shale gas reservoir in a work area;
b) acquiring acoustic time difference AC and density DEN logging information of a shale gas reservoir to be predicted;
c) calculating the acoustic time difference logging porosity POR of the corresponding depth point by using the acoustic time difference AC logging data of the shale gas reservoir to be predicted in the step b)AC；
d) Calculating the total organic carbon content TOC of the corresponding depth point by using the density DEN logging information of the point to be predicted of the well shale gas reservoir in the step b)DEN(ii) a Or Total Organic Carbon (TOC) content of shale gas reservoir measured by logging geochemical methodDEN；
e) Obtaining total organic carbon content TOC by utilizing apparent organic matter conversion efficiency eta of shale gas reservoir and step d)DENAnd c) solving the acoustic time difference logging porosity PORACData according to model PORTOC＝η·TOCDEN·PORACCalculating the shale gas reservoir organic porosity POR of the well to be predictedTOC。
3. The method for correcting the irreducible water saturation of the shale gas reservoir as claimed in claim 2, wherein in the step a), the apparent organic matter conversion efficiency η of the shale gas reservoir is obtained by the following method:
a1) obtaining shale gas reservoir organic porosity POR obtained by laboratory analysis of coring well in work areaTOC1；
a2) Calculating acoustic time difference logging porosity POR of corresponding depth point by using acoustic time difference logging data of shale gas reservoirAC1；
The calculation formula is PORAC1＝A1·AC－B1，
In the formula of PORAC1 is the acoustic moveout logging porosity, in units,
wherein AC is a sonic logging value of a corresponding depth point, A1 and B1 are area scale coefficients of the AC, A1 is 0.0621 in Fuling area, and B1 is 11.089;
a3) calculating the total organic carbon content TOCDEN1 of the corresponding depth point by using the density DEN data of the shale gas reservoir;
the formula is TOCDEN1 ═ M1 · (N1-DEN),
wherein TOCDEN1 is the total organic carbon content,
DEN is the density log of the corresponding depth point, in g/cm3,
m1 and N1 are DEN area scale coefficients,
or the total organic carbon content of the shale gas reservoir measured by a logging geochemical method is used for replacing TOCDEN1；
a4) Calculating organic porosity ratio value POR of shale gas reservoir corresponding to each pointTOC1/PORAC1, TOC corresponding to each pointDEN1, modeling POR by least squaresTOC1/PORAC1＝η·TOCDENAnd 1, determining apparent organic matter conversion efficiency eta of the shale gas reservoir, wherein eta is generally expressed by decimal.
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| CN116774279A (en) * | 2023-06-14 | 2023-09-19 | 西南石油大学 | Shale water saturation prediction method based on gas-water balance lithology combination unit |
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