CN101413388A - Method for obtaining oil-water common-layer original oil-containing saturation degree and method for estimating non-test oil-water common-layer original oil-containing saturation degree - Google Patents

Method for obtaining oil-water common-layer original oil-containing saturation degree and method for estimating non-test oil-water common-layer original oil-containing saturation degree Download PDF

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CN101413388A
CN101413388A CNA2008102095918A CN200810209591A CN101413388A CN 101413388 A CN101413388 A CN 101413388A CN A2008102095918 A CNA2008102095918 A CN A2008102095918A CN 200810209591 A CN200810209591 A CN 200810209591A CN 101413388 A CN101413388 A CN 101413388A
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oil
layer
water
saturation
common
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闫伟林
李郑辰
殷树军
杨永军
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Daqing Oilfield Co Ltd
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Daqing Oilfield Co Ltd
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Abstract

The invention relates to a method for acquiring the initial oil saturation of an oil-water layer and a method for estimating the initial oil saturation of the oil-water layer of untested oil, which relate to a method for calculating the initial oil saturation in a reserve parameter log interpretation. The method solves the problem of large calculation error in the prior method for acquiring the initial oil saturation of the oil-water layer. In the method for acquiring the initial oil saturation of the oil-water layer, the initial oil saturation of a tested oil layer of the oil-water layer is calculated by application of an initial oil saturation model of the oil layer first, and corrected according to interpenetration data and oil testing data to obtain the initial oil saturation of the oil-water layer of tested oil. The method is suitable for the oil-water layer with poor correlation between the initial oil saturation and the resistivity and can be used for calculating the petroleum reserve by the volumetric method. The method for estimating the initial oil saturation of the oil-water layer of the untested oil according to the interpenetration data and the oil testing data is to estimate the initial oil saturation of the oil-water layer of the untested oil by applying and researching the average moisture content of the oil-water layer of a working area.

Description

Obtain the method for oil-water common-layer original saturation ratio and estimate the not method of formation testing oil-water common-layer original saturation ratio
Technical field
The present invention relates to calculate in the reserves parameter well log interpretation method of initial oil saturation,
Background technology
Along with the continuous development of petroleum exploration in China, the ratio of oil-water common-layer constantly increases in the newly-increased petroleum reserves, and the initial oil saturation of accurately calculating oil-water common-layer becomes more and more important.
Applicable elements: the method for this calculating oil-water common-layer original saturation ratio is suitable for initial oil saturation and the relatively poor oil-water common-layer of resistivity correlation.
The method of calculating similar oil reservoir profit common-layer original oil saturation at present is that oil-water common-layer is considered as oil reservoir, the initial oil saturation interpretation model of using oil reservoir calculates " looking the oil reservoir initial oil saturation ", direct initial oil saturation as oil-water common-layer.The applicable elements of this method is oil-water common-layer original saturation ratio and resistivity good relationship, thereby can accurately calculate the oil-water common-layer original saturation ratio according to parameters such as resistivity.For initial oil saturation and the relatively poor oil-water common-layer of reservoir resistivity correlation, error calculated is bigger.
Summary of the invention
In order to solve the existing bigger problem of error of calculation that the oil-water common-layer original saturation intent exists that obtains, the present invention proposes and a kind ofly obtain the method for oil-water common-layer original saturation ratio and estimate the not method of formation testing oil-water common-layer original saturation ratio.
The detailed process that obtains the method for oil-water common-layer original saturation ratio is:
Step 1, obtain natural gamma relative value Δ GR according to the gamma ray log curve:
On the gamma ray log curve, read natural gamma value GR, the interval of interest sharp sand rock stratum natural gamma value GR of oil-water common-layer MinWith interval of interest pure shale interval natural gamma value GR Max, then by formula:
ΔGR＝(GR-GR min)/(GR max-GR min)
Obtain natural gamma relative value Δ GR, wherein target zone natural gamma value GR, interval of interest sharp sand rock stratum natural gamma value GR MinWith interval of interest pure shale layer natural gamma value GR MaxUnit all are API, the unit of natural gamma relative value Δ GR is f;
Step 2, set up the shale content interpretation model:
Carry out one-variable linear regression with core analysis shale content data and natural gamma, set up the shale content interpretation model:
V sh＝a·ΔGR+b，
Shale content V wherein ShBe percentage, a, b are coefficients; The described shale content interpretation model of natural gamma relative value Δ GR substitution of the oil-water common-layer that step 1 is obtained obtains the shale content V of oil-water common-layer Sh
Step 3, set up the effecive porosity interpretation model:
Use acoustic travel time logging curve, shale content and core analysis effecive porosity and carry out binary linear regression, set up the effecive porosity interpretation model:
φ＝a·AC+b·V sh+c，
Effecive porosity φ is a percentage, and a, b, c are coefficients;
The interval transit time value AC of oil-water common-layer, the shale content value V that step 2 obtains will be read ShSubstitution effecive porosity interpretation model, the effecive porosity φ of acquisition oil-water common-layer;
Step 4, in the oil reservoir of sealed coring well, set up the original water saturation model of oil reservoir:
Utilize the relation of irreducible water saturation and air permeability to set up the irreducible water saturation interpretation model, promptly determine the original water saturation model of oil reservoir, be i.e. the original water saturation model of rerum natura by air permeability:
Sw Oil=f (K),
Sw in the formula OilBe the original water saturation of oil reservoir, unit is a percentage, and f () is the empirical function between water saturation and the permeability, usually may be linear function, power function, exponential function or logarithmic function, concrete function can preferably draw by index of correlation, and K is an air permeability, and unit is mD;
Step 5, set up the not original water saturation interpretation model of core hole oil reservoir:
According to the original moisture full water saturation that obtains the conventional layer of coring of the described oil reservoir of step 4, and carry out binary linear regression with effecive porosity, dark side direction resistivity, set up the not original water saturation interpretation model of core hole oil reservoir, promptly electrical original water saturation model:
logS w＝a·logφ+b·logR LLD+c，
R in the formula LLDBe dark side direction resistivity, unit is Ω m, and a, b, c are coefficients;
Oil-water common-layer is considered as oil reservoir, with the dark side direction resistivity R of the local area oil-water common-layer that reads LLD, the oil-water common-layer that will obtain according to the described effecive porosity interpretation model of step 3 the effecive porosity φ substitution original water saturation interpretation model of core hole oil reservoir not, obtain oil-water common-layer " looking the oil reservoir initial oil saturation ";
Step 6, set up a plurality of different water cut rate correspondences oil-water common-layer water saturation correction amount delta Sw with and look calibration model between the original water saturation Sw of oil reservoir:
ΔSw＝a·Sw+b，
In the formula oil-water common-layer look oil reservoir water saturation Sw, oil-water common-layer water saturation correction amount delta Sw all is a percentage, a, b are coefficients;
Step 7, obtain the actual wet oil saturation ratio Sw of the oil-water common-layer of formation testing With layer, and then obtain oil saturation So With layer:
For the oil-water common-layer of formation testing, obtain moisture content Fw according to the formation testing result, select the calibration model in the step 6 to obtain oil-water common-layer water saturation correction amount delta Sw under this moisture content condition according to described moisture content again; Or according to adjacent two moisture content Fw 1, Fw 2Corresponding calibration model calculates Δ Sw respectively 1, Δ Sw 2, and obtain final Δ Sw by linear interpolation:
ΔSw = Δ Sw 1 + ( ΔSw 2 - Δ Sw 1 ) Fw - Fw 1 Fw 2 - Fw 1
Look oil reservoir water saturation Sw according to what step 5 obtained this layer, determine the actual wet oil saturation ratio Sw of oil-water common-layer With layer:
Sw With layer=Sw+ Δ Sw,
The actual water saturation Sw of oil-water common-layer in the formula With layerUnit is a percentage,
Because the water saturation and the oil saturation sum of oil-water common-layer are 100, and then can determine the actual oil saturation So of oil-water common-layer With layer=100-Sw With layer
Adopt method of the present invention to obtain the initial oil saturation of oil-water common-layer accurately, realize the accurate calculating of initial oil saturation according to oozing data and well-log information mutually.
The principle of the method for the invention is: ooze the relation that experimental result has reflected reservoir moisture content and water saturation mutually, increase along with water saturation, reservoir carries out the transition to profit with producing gradually by producing pure oil (moisture content is 0%), finally become and produce pure water layer (moisture content is 100%), therefore, moisture content and and change procedure can reflect the change procedure of oil-water common-layer original saturation ratio.Oozing mutually on the plot of water cut, when moisture content was 0%, corresponding water saturation was the original water saturation of net pay zone; General when moisture content is 10% to 90%, corresponding water saturation is the water saturation of oil-water common-layer.Under the condition of certain moisture content (is 50% o'clock as moisture content), the difference of oil-water common-layer water saturation and net pay zone water saturation can be used as oil-water common-layer water saturation correcting value.
Oozing analysis mutually shows: for moisture content is the oil-water common-layer of certain value, and oil-water common-layer water saturation correcting value increases with the increase of reservoir porosity; Because " looking the original water saturation of oil reservoir " reduces with the increase of reservoir porosity, therefore, oil-water common-layer water saturation correcting value reduces with the increase of " looking the original water saturation of oil reservoir ".In the time of can setting up the different water cut rate thus, the calibration model that oil-water common-layer water saturation correcting value changes with " looking the original water saturation of oil reservoir ".
For the oil-water common-layer of formation testing, can obtain moisture content according to the formation testing result, calculate " looking the oil reservoir water saturation " of this layer this moment, just can obtain with a layer water saturation correcting value, and then the original water saturation of definite oil-water common-layer.
This method is particularly suitable for initial oil saturation and the relatively poor oil-water common-layer of resistivity correlation, can be used for volumetric method and calculate petroleum reserves.
The present invention also provides the not method of formation testing oil-water common-layer original saturation ratio of a kind of estimation, and it has increased following steps on the basis of said method:
Step 8, obtain the not initial oil saturation of formation testing oil-water common-layer:
Add up the moisture content in all each districts, and the average moisture content of the calculating whole district, use then and ooze data mutually, when setting up moisture content and being average moisture content, the relational model of oil-water common-layer water saturation correcting value and same layer " looking the oil reservoir water saturation ", obtaining the not original water saturation approximate correction amount of formation testing oil-water common-layer, and then the water saturation of definite oil-water common-layer, is the oil saturation that 100 condition obtains oil-water common-layer according to water saturation and oil saturation sum then.
Said method is the average moisture content according to whole district's oil-water common-layer, estimates the not initial oil saturation of formation testing oil-water common-layer with similar method.
At first, add up the average moisture content of whole district's oil-water common-layer according to local area individual layer oil test data.
Oozing analysis mutually shows: for moisture content is the oil-water common-layer of certain value, and oil-water common-layer water saturation correcting value increases with the increase of reservoir porosity; Because " looking the original water saturation of oil reservoir " reduces with the increase of reservoir porosity, therefore, oil-water common-layer water saturation correcting value reduces with the increase of " looking the original water saturation of oil reservoir ".In the time of can setting up moisture content thus and be average moisture content, the relation of oil-water common-layer water saturation correcting value and " looking the oil reservoir water saturation ".And then according to " looking the original water saturation of oil reservoir " calculating oil-water common-layer water saturation correcting value.
" looking the original water saturation of oil reservoir " of oil-water common-layer adds that oil-water common-layer water saturation correcting value is the original water saturation of oil-water common-layer.
The present invention is applicable to that the average moisture content of research work area oil-water common-layer estimates not formation testing oil-water common-layer original saturation ratio.
Description of drawings
Fig. 1 is shale content and the GR relative value graph of a relation in the specific embodiment three;
Fig. 2 is core analysis and the well log interpretation effecive porosity graph of a relation in the specific embodiment three;
Fig. 3 is oil reservoir water saturation and the air permeability graph of a relation in the specific embodiment three;
Fig. 4 is the electrical calculating initial oil saturation graph of a relation in the specific embodiment three;
Fig. 5 determines oil-water common-layer water saturation correcting value schematic diagram in the specific embodiment three with the relative permeability data;
When Fig. 6 is a different water cut rate in the specific embodiment three, with layer water saturation correcting value with layer " looking a oil reservoir water saturation " graph of a relation;
Fig. 7 for the not formation testing in the specific embodiment three with layer water saturation correcting value and formation testing not with layer " looking a oil reservoir water saturation " graph of a relation;
Fig. 8 is core analysis and the well log interpretation effecive porosity graph of a relation in the specific embodiment four;
Fig. 9 is oil reservoir water saturation and the air permeability graph of a relation in the specific embodiment four;
Figure 10 is the electrical calculating initial oil saturation graph of a relation in the specific embodiment four;
When Figure 11 is a different oil content in the specific embodiment four, with layer oil saturation correcting value with layer " looking a oil reservoir oil saturation " graph of a relation;
Figure 12 for the not formation testing in the specific embodiment four with layer oil saturation correcting value and formation testing not with layer " looking a oil reservoir oil saturation " graph of a relation.
The specific embodiment
The specific embodiment one, the described a kind of detailed process that obtains the method for oil-water common-layer original saturation ratio of present embodiment are:
Step 1, obtain natural gamma relative value Δ GR according to the gamma ray log curve:
On the gamma ray log curve, read natural gamma value GR, the interval of interest sharp sand rock stratum natural gamma value GR of oil-water common-layer MinWith interval of interest pure shale interval natural gamma value GR Max, then by formula:
ΔGR＝(GR-GR min)/(GR max-GR min)
Obtain natural gamma relative value Δ GR, wherein target zone natural gamma value GR, interval of interest sharp sand rock stratum natural gamma value GR MinWith interval of interest pure shale layer natural gamma value GR MaxUnit all are API, the unit of natural gamma relative value Δ GR is f;
Step 2, set up the shale content interpretation model:
Carry out one-variable linear regression with core analysis shale content data and natural gamma, set up the shale content interpretation model:
V sh＝a·ΔGR+b，
Shale content V wherein ShBe percentage, a, b are coefficients; The described shale content interpretation model of natural gamma relative value Δ GR substitution of the oil-water common-layer that step 1 is obtained obtains the shale content V of oil-water common-layer Sh
Step 3, set up the effecive porosity interpretation model:
Use acoustic travel time logging curve, shale content and core analysis effecive porosity and carry out binary linear regression, set up the effecive porosity interpretation model:
φ＝a·AC+b·V sh+c，
Effecive porosity φ is a percentage, and a, b, c are coefficients;
The interval transit time value AC of oil-water common-layer, the shale content value V that step 2 obtains will be read ShSubstitution effecive porosity interpretation model, the effecive porosity φ of acquisition oil-water common-layer;
Step 4, in the oil reservoir of sealed coring well, set up the original water saturation model of oil reservoir:
Utilize the relation of irreducible water saturation and air permeability to set up the irreducible water saturation interpretation model, promptly determine the original water saturation model of oil reservoir, be i.e. the original water saturation model of rerum natura by air permeability:
Sw Oil=f (K),
The original water saturation Sw of oil reservoir in the formula OilBe percentage, f () is the empirical function between water saturation and the permeability, may be linear function, power function, exponential function or logarithmic function usually, and concrete function can preferably draw by index of correlation, and K is an air permeability, and unit is mD;
Step 5, set up the not original water saturation interpretation model of core hole oil reservoir:
According to the original moisture full water saturation that obtains the conventional layer of coring of the described oil reservoir of step 4, and carry out binary linear regression with effecive porosity, dark side direction resistivity, set up the not original water saturation interpretation model of core hole oil reservoir, promptly electrical original water saturation model:
logS w＝a·logφ+b·logR LLD+c，
R in the formula LLDBe dark side direction resistivity, unit is Ω m, and a, b, c are coefficients;
Oil-water common-layer is considered as oil reservoir, with the dark side direction resistivity R of the local area oil-water common-layer that reads LLD, the oil-water common-layer that will obtain according to the described effecive porosity interpretation model of step 3 the effecive porosity φ substitution original water saturation interpretation model of core hole oil reservoir not, obtain oil-water common-layer " looking the oil reservoir initial oil saturation ";
Step 6, set up a plurality of different water cut rate correspondences oil-water common-layer water saturation correction amount delta Sw with and look calibration model between the original water saturation Sw of oil reservoir:
ΔSw＝a·Sw+b，
In the formula oil-water common-layer look oil reservoir water saturation Sw, oil-water common-layer water saturation correction amount delta Sw all is a percentage, a, b are coefficients;
Step 7, obtain the actual wet oil saturation ratio Sw of the oil-water common-layer of formation testing With layer:
For the oil-water common-layer of formation testing, the result obtains moisture content according to formation testing, and the calibration model according to moisture content corresponding selection step 6 obtains obtains oil-water common-layer water saturation correction amount delta Sw under this moisture content condition; Or according to adjacent two moisture content Fw 1, Fw 2Corresponding calibration model calculates Δ Sw respectively 1, Δ Sw 2, and obtain final Δ Sw by linear interpolation:
ΔSw = Δ Sw 1 + ( ΔSw 2 - Δ Sw 1 ) Fw - Fw 1 Fw 2 - Fw 1
According to " looking the oil reservoir initial oil saturation " Sw of the definite oil-water common-layer of step 5, determine the actual wet oil saturation ratio Sw of oil-water common-layer With layer:
Sw With layer=Sw+ Δ Sw,
The actual water saturation Sw of oil-water common-layer in the formula With layerBe percentage,
Because the water saturation and the oil saturation sum of oil-water common-layer are 100, and then can determine the actual oil saturation So of oil-water common-layer With layer=100-Sw With layer
Because in oil reservoir, water saturation is irreducible water saturation, therefore, the irreducible water saturation interpretation model in step 4 is exactly a water saturation.
At a plurality of moisture content described in the step 6, can select according to actual conditions, generally be between 0% to 100%, evenly to be divided into a plurality of intervals, select then each interval end points set up corresponding oil-water common-layer water saturation correction amount delta Sw with and look calibration model between the original water saturation Sw of oil reservoir.
The principle of step 6 is: ooze the relation that experimental result has reflected reservoir moisture content and water saturation mutually, on the plot of water cut that the relative permeability data is determined, when moisture content was 0%, corresponding water saturation was the original water saturation of net pay zone; Moisture content is the original water saturation that 10% to 90% o'clock pairing water saturation is oil-water common-layer.Under the condition of certain moisture content (is 50% o'clock as moisture content), the difference of the water saturation of oil-water common-layer and the water saturation of net pay zone can be used as the water saturation correcting value of the oil-water common-layer of formation testing.Studies show that: for moisture content is the oil-water common-layer of a fixed value, and oil-water common-layer water saturation correcting value reduces with the increase of " looking the oil reservoir water saturation ", utilizes this relation to set up oil-water common-layer oil saturation model.And then according to moisture content and " looking the original water saturation of oil reservoir " of formation testing oil-water common-layer are calculated oil-water common-layer water saturation correcting value." looking the original water saturation of oil reservoir " of oil-water common-layer adds that oil-water common-layer water saturation correcting value is the original water saturation of oil-water common-layer.
The principle of step 7 is: according to the moisture content of the oil-water common-layer of formation testing, select the calibration model in the corresponding step 6, the principle of selecting is, select the corresponding calibration model of moisture content of described moisture content and the difference minimum of the described a plurality of moisture content of step 6, obtain oil-water common-layer water saturation correcting value; Can also select two adjacent calibration models to calculate respectively and obtain two correcting values, get its average then as final correcting value." looking the oil reservoir water saturation " of oil-water common-layer and original water saturation oil-water common-layer water saturation correcting value and that be oil-water common-layer.
The method of the described acquisition oil-water common-layer original of present embodiment saturation ratio, can make full use of the laboratory and ooze analysis of data mutually, comprehensive logging, core analysis, the initial oil saturation that multiple data is calculated oil-water common-layer such as ooze mutually, calculate the common-layer original oil saturation more exactly, relative error is less than 8%.
The specific embodiment two: the described estimation of present embodiment is the method for formation testing oil-water common-layer original saturation ratio not, is on the basis of the method for the specific embodiment one described acquisition oil-water common-layer original saturation ratio, has increased following steps:
Step 8, obtain the not average original water saturation of formation testing oil-water common-layer:
Add up the moisture content in all each districts, and the average moisture content of the calculating whole district, use then and ooze data mutually, when setting up moisture content and being average moisture content, the relational model of oil-water common-layer water saturation correcting value and same layer " looking the oil reservoir water saturation ", obtaining the not original water saturation approximate correction amount of formation testing oil-water common-layer, and then the water saturation of definite oil-water common-layer, is the oil saturation that 100 relation obtains oil-water common-layer according to water saturation and oil saturation sum then.
Present embodiment estimates the not initial oil saturation of formation testing oil-water common-layer according to the average moisture content of whole district's oil-water common-layer.
The specific embodiment three: present embodiment is the example of the method for the specific embodiment one described acquisition oil-water common-layer original saturation ratio.
Present embodiment is that example describes with G oil field P oil reservoir,
Step 1, obtain natural gamma relative value Δ GR according to the gamma ray log curve:
On the gamma ray log curve, read natural gamma value GR, the interval of interest sharp sand rock stratum natural gamma value GR of oil-water common-layer MinWith interval of interest pure shale interval natural gamma value GR Max, then by formula:
ΔGR＝(GR-GR min)/(GR max-GR min)
Obtain to calculate natural gamma relative value Δ GR;
Step 2, set up shale content interpretation model: V Sh=a Δ GR+b,
The data that preferred 25 mouthfuls of wells of local area are 101 layers, its shale content excursion is 6.0～39.3%, average is 14.9%, represented the variation of whole district's shale content preferably, utilize the core analysis shale content and the gamma ray log data of these layers to carry out simple linear regression analysis, set up the shale content interpretation model.Shown in Figure 1 referring in the Figure of description determined coefficient a=42.65 by returning, b=5.912, and the described shale content interpretation model of substitution is:
V sh＝42.65ΔGR+5.912，
The one-variable linear regression coefficient R 2=0.673, shale content and GR relative value good relationship are described;
Step 3, set up effecive porosity interpretation model: φ=aAC+bV Sh+ c,
The data that preferred 33 mouthfuls of wells of local area are 132 layers, its effecive porosity excursion is 5.1～23.9%, average is 15.9%, has represented the variation of whole district's effecive porosity preferably.Utilize core analysis degree of porosity and shale content, the interval transit time of these layers to carry out the binary linear regression analysis, set up P oil reservoir effecive porosity interpretation model.Shown in Figure 2 referring in the Figure of description determined coefficient a=0.6115 by returning, b=-0.1264, and c=-30.36, the described effecive porosity interpretation model of substitution is:
φ＝0.6115AC-0.1264V sh-30.36，
The binary linear regression multiple correlation coefficient is R 2=0.847; Effecive porosity and interval transit time, shale content good relationship are described;
Step 4, in the oil reservoir of sealed coring well, set up the original water saturation model of oil reservoir: Sw Oil=f (K),
Use the original water saturation of core analysis and the air permeability data of 27 oil reservoir samples of 1 mouthful of well of local area, its air permeability excursion is 0.21mD～115.00mD, and average out to 16.21mD has represented the variation of whole district's air permeability preferably.Utilize the data of the core analysis of these samples, set up air permeability and oil reservoir water saturation graph of a relation, shown in Figure 3 referring in the Figure of description, the i.e. original water saturation model of rerum natura, described function f ()=57.23K -0.1050, coefficient R 2=0.689;
Corresponding initial oil saturation So is: So=100-Sw.
Step 5, set up the not original water saturation interpretation model of core hole oil reservoir:
logS w＝a·logφ+b·logR LLD+c，
Because the permeability error of well log interpretation is bigger, the original water saturation model of oil reservoir that step 4 obtains is only applicable to have in the core hole reservoir of core analysis permeability data.In order to calculate the not water saturation of core hole oil reservoir, preferred 116 layers of coring of 27 mouthfuls of wells of local area, its effecive porosity excursion is 9.4%～24.5%, average out to 16.1%, its air permeability excursion is 0.14mD～159.85mD, average out to 19.87mD, the variation of having represented whole district hole to ooze preferably.The original water saturation model of oil reservoir that applying step four obtains calculates the water saturation of described 116 layers of coring, and carry out mathematic statistics with effecive porosity, dark side direction resistivity and return, set up the not original water saturation interpretation model of core hole oil reservoir, promptly electrical original water saturation model:
logS w＝2.757-0.7678logφ-0.1275logR LLD
Coefficient R 2=0.812.
The original water saturation relationship model of rerum natura that obtains in above-mentioned electrical original water saturation model and the step 4 is good, referring to the Fig. 4 in the Figure of description.
Oil-water common-layer is considered as oil reservoir, read the dark side direction resistivity of local area oil-water common-layer, calculate effecive porosity, " the looking the oil reservoir initial oil saturation " that can calculate oil-water common-layer according to the original water saturation interpretation model of described not core hole oil reservoir according to the described effecive porosity interpretation model of step 3.
Local area oil reservoir average effective degree of porosity is 18.1%, and average deep lateral apparent resistivity is 17.4 Ω m, and using not the original water saturation interpretation model of core hole oil reservoir, to calculate average oil saturation be 56.8%; Local area oil-water common-layer average effective degree of porosity is 16.9%, and average deep lateral apparent resistivity is 14.5 Ω m, and using not the original water saturation interpretation model of core hole oil reservoir, to calculate average oil saturation be 53.3%.Illustrate that oil reservoir that calculates and oil-water common-layer original saturation ratio differ also little, need proofread and correct the oil-water common-layer original saturation ratio owing to the rerum natura of local area oil reservoir and oil-water common-layer, electrically differ all little.
2 mouthfuls of sealed coring well oil reservoirs of local area average effective degree of porosity is 16.9%, has represented the variation of whole district's oil reservoir effecive porosity preferably, and surveying average oil saturation is 53.9%; 2 mouthfuls of sealed coring well oil-water common-layer average effective degree of porosity are 16.3%, have also represented the variation of whole district's oil-water common-layer effecive porosity preferably, and surveying average oil saturation is 43.6%.Illustrate that the oil reservoir initial oil saturation that the original water saturation interpretation model of using core hole oil reservoir not calculates is accurate substantially, " to look the oil reservoir initial oil saturation " higher and use oil-water common-layer that the original water saturation interpretation model of described not core hole oil reservoir calculates.Reason is that above-mentioned model is based on oil reservoir foundation, is applicable to oil reservoir, and is not suitable for the oil-water common-layer close with the oil reservoir electrical property feature.
Step 6, set up a plurality of different water cut rate correspondences oil-water common-layer water saturation correction amount delta Sw with and look calibration model between the original water saturation Sw of oil reservoir:
ΔSw＝a·Sw+b，
Ooze experimental result mutually and reflected the relation of reservoir moisture content and water saturation, increase along with water saturation, reservoir carries out the transition to profit with producing gradually by producing pure oil (moisture content is 0%), finally become and produce pure water layer (moisture content is 100%), therefore, moisture content and and change procedure can reflect the change procedure of oil-water common-layer original saturation ratio.Oozing mutually on the plot of water cut, when moisture content was 0%, corresponding water saturation was the original water saturation of net pay zone; General when moisture content is 10%-90%, corresponding water saturation is the water saturation of oil-water common-layer.Under the condition of certain moisture content (is 50% o'clock as moisture content), the difference of oil-water common-layer water saturation and net pay zone water saturation can be used as oil-water common-layer water saturation correcting value, shown in Figure 5 referring in the Figure of description.
Ooze the moisture content model mutually in order to set up, preferred 12 samples of 5 mouthfuls of wells of local area ooze data mutually, these 12 sample air permeability variation scopes are 1.91mD～76.80mD, average out to 26.41mD; The effecive porosity excursion is 13.3%～18.3%, and average out to 16.3% has been represented the variation of whole district's effecive porosity preferably.The analysis of oozing mutually that these 12 sample laboratories are recorded shows: for moisture content is the oil-water common-layer of certain value, and oil-water common-layer water saturation correcting value increases with the increase of reservoir porosity; Because " looking the original water saturation of oil reservoir " reduces with the increase of reservoir porosity, therefore, oil-water common-layer water saturation correcting value reduces with the increase of " looking the original water saturation of oil reservoir ", referring to the Fig. 5 in the Figure of description.In the time of can setting up different water cut rate Fw thus, oil-water common-layer water saturation correction amount delta Sw is with the calibration model of " looking the original water saturation Sw of oil reservoir ", shown in Figure 6 referring in the Figure of description:
During Fw=90%: Δ Sw=-0.8206Sw+52.80, R 2=0.644;
During Fw=80%: Δ Sw=-0.7299Sw+45.71, R 2=0.650;
During Fw=70%: Δ Sw=-0.6518Sw+39.91, R 2=0.649;
During Fw=60%: Δ Sw=-0.5778Sw+34.69, R 2=0.642;
During Fw=50%: Δ Sw=-0.4986Sw+29.46, R 2=0.637;
During Fw=40%: Δ Sw=-0.4104Sw+23.88, R 2=0.639;
During Fw=30%: Δ Sw=-0.3223Sw+18.39, R 2=0.632;
During Fw=20%: Δ Sw=-0.2162Sw+12.28, R 2=0.575;
During Fw=10%: Δ Sw=-0.1033Sw+5.897, R 2=0.510.
Step 7, obtain the actual water saturation Sw of the oil-water common-layer of formation testing With layer:
As seen from Figure 6: for the oil-water common-layer of formation testing, can obtain moisture content Fw, select suitable updating formula to calculate water saturation correction amount delta Sw according to Fw according to the formation testing result; If reservoir producing water ratio Fw is between the producing water ratio Fw of certain two formula 1, Fw 2Between, can calculate water saturation correction amount delta Sw respectively with these two formula 1, Δ Sw 2, and result of calculation is carried out linear interpolation obtain final water saturation correction amount delta Sw:
ΔSw = Δ Sw 1 + ( ΔSw 2 - Δ Sw 1 ) Fw - Fw 1 Fw 2 - Fw 1
According to " looking the original water saturation of oil reservoir " Sw that step 5 is calculated, just can use the wet oil saturation ratio of determining oil-water common-layer with layer water saturation correction amount delta Sw:
Sw With layer=Sw+ Δ Sw.
When needs obtain the original water saturation of formation testing oil-water common-layer not, continue to carry out next step:
Step 8, obtain the not original water saturation of formation testing oil-water common-layer:
For calculating the not original water saturation of formation testing oil-water common-layer, added up the average moisture content of local area: single examination oil-water common-layer that local area does not carry out the pressure break formation testing has 11 layers of 10 mouthfuls of wells, and its average moisture content is 47.8%.
12 samples described in the applying step six ooze data mutually, setting up moisture content is 47.8% o'clock, the relational model of oil-water common-layer water saturation correcting value and same layer " looking the oil reservoir water saturation " is referring to the Fig. 7 in the Figure of description, can calculate the not original water saturation correcting value of formation testing oil-water common-layer, and then the wet oil saturation ratio of definite oil-water common-layer:
During Fw=47.8%: Δ Sw=-0.4800Sw+28.25, index of correlation: R 2=0.638
According to Sw With layer=Sw+ Δ Sw obtains the not original water saturation of formation testing oil-water common-layer.
In order to verify the precision of calculation results of the described method of present embodiment, result of calculation and 6 oil-water common-layer original saturation ratios of 2 mouthfuls of sealed coring well actual measurements are contrasted, concrete parameter is referring to table 1.From table one as seen, using the average initial oil saturation of this method calculating oil-water common-layer is 44.4%, near sealed coring well result (43.6%); Oil-water common-layer original saturation ratio average relative error is 6.1%, less than 8%, satisfies the requirement of reserves standard.
Table 1: oil-water common-layer original saturation ratio precision contrast table
Figure A200810209591D00171
The specific embodiment four: present embodiment is another example of the method for the specific embodiment one described acquisition oil-water common-layer original saturation ratio, in the present embodiment, what set up in step 6 is the oil saturation calibration model of a plurality of different water cut rate correspondences.
Present embodiment is that example describes with A-E oil field S oil reservoir,
Step 1, obtain natural gamma relative value Δ GR according to the gamma ray log curve:
On the gamma ray log curve, read natural gamma value GR, the interval of interest sharp sand rock stratum natural gamma value GR of oil-water common-layer MinWith interval of interest pure shale interval natural gamma value GR Max, then by formula:
ΔGR＝(GR-GR min)/(GR max-GR min)
Obtain to calculate natural gamma relative value Δ GR;
Step 2 and step 3, set up the effecive porosity interpretation model
Because A-E oil field S oil reservoir shale content data is less, can't set up the shale content interpretation model, uses interval transit time and natural gamma relative value and directly set up the effecive porosity interpretation model.
The data of preferred 79 layers of 21 mouthfuls of wells of local area, its effecive porosity excursion is 20.3～36.7%, average is 29.9%, has represented the variation of whole district's effecive porosity preferably.Utilize core analysis degree of porosity and interval transit time, the natural gamma relative value of these layers to carry out the binary linear regression analysis, set up S oil reservoir effecive porosity interpretation model.Shown in Figure 8 referring in the Figure of description determined coefficient a=0.2000 by returning, b=-5.924, and c=9.449, the described effecive porosity model of substitution is:
Φ＝0.2000AC-5.924ΔGR+9.449
The binary linear regression multiple correlation coefficient is R 2=0.567; Effecive porosity and interval transit time, shale content good relationship are described;
Step 4, in the oil reservoir of sealed coring well, set up the original water saturation model of oil reservoir: Sw Oil=f (K),
Because A-E oil field S oil reservoir does not have sealed coring well, but local area belongs to heavy crude reservoir, the core analysis data that can use 1 mouthful of freezing core hole replaces sealed coring well data to determine the original water saturation of core analysis.
Use the original water saturation of core analysis and the air permeability data of 28 oil reservoir samples of 1 mouthful of well of local area, its air permeability excursion is 42.50mD～4317mD, and average out to 1130mD has represented the variation of whole district's air permeability preferably.Utilize the data of the core analysis of these samples, set up air permeability and oil reservoir water saturation graph of a relation, shown in Figure 9 referring in the Figure of description, the i.e. original moisture and degree model of rerum natura, described function f ()=226.1K -0.2600, coefficient R 2=0.705;
Corresponding initial oil saturation So is: So=100-Sw.
Step 5, set up the not original water saturation interpretation model of core hole oil reservoir:
logS w＝a·logφ+b·logR LLD+c，
Because the permeability error of well log interpretation is bigger, the original water saturation model of oil reservoir that step 4 obtains is only applicable to have in the core hole reservoir of core analysis permeability data.In order to calculate the not water saturation of core hole oil reservoir, preferred 9 layers of coring of 6 mouthfuls of wells of local area, its effecive porosity excursion is 25.0%～35.1%, average out to 30.5%, its air permeability excursion is 46.40mD～2921.33mD, average out to 756.84mD, the variation of having represented whole district hole to ooze preferably.The original water saturation model of oil reservoir that applying step four obtains calculates the water saturation of described 9 layers of coring, and carry out mathematic statistics with effecive porosity, dark side direction resistivity and return, set up the not original water saturation interpretation model of core hole oil reservoir, promptly electrical original water saturation model:
logS w＝4.339-1.546logφ-0.3038logR LLD
Coefficient R 2=0.977.
The original water saturation relationship model of rerum natura that obtains in above-mentioned electrical original water saturation model and the step 4 is good, referring to the Figure 10 in the Figure of description.
Oil-water common-layer is considered as oil reservoir, read the dark side direction resistivity of local area oil-water common-layer, calculate effecive porosity, " the looking the oil reservoir initial oil saturation " that can calculate oil-water common-layer according to the original water saturation interpretation model of described not core hole oil reservoir according to the described effecive porosity interpretation model of step 3.
Local area oil reservoir average effective degree of porosity is 31.3%, and average deep lateral apparent resistivity is 27.7 Ω m, and using not the original water saturation interpretation model of core hole oil reservoir, to calculate average oil saturation be 56.3%; Local area oil-water common-layer average effective degree of porosity is 32.5%, and average deep lateral apparent resistivity is 17.7 Ω m, and using not the original water saturation interpretation model of core hole oil reservoir, to calculate average oil saturation be 56.0%.Illustrate since the rerum natura of local area oil-water common-layer a little more than oil reservoir, oil-water common-layer electrically a little less than oil reservoir, oil reservoir that calculates and oil-water common-layer original saturation ratio are more or less the same, and need proofread and correct the oil-water common-layer original saturation ratio.
Step 6, set up a plurality of different water cut rate correspondences oil-water common-layer oil saturation correction amount delta So with and look calibration model between the oil reservoir initial oil saturation So:
ΔSo＝a·So+b。
Because oil saturation and water saturation and be 100%, so, equate on oil saturation correcting value and the water saturation correcting value numerical value, that is:
So＝100-Sw，
ΔSw＝ΔSo，
Can determine oil saturation correction amount delta So and the relation of looking oil reservoir water saturation So with the relation of looking oil reservoir oil saturation Sw according to oil-containing water saturation correction amount Δ Sw thus.
Ooze experimental result mutually and reflected the relation of reservoir moisture content and water saturation, increase along with water saturation, reservoir carries out the transition to profit with producing gradually by producing pure oil (moisture content is 0%), finally become and produce pure water layer (moisture content is 100%), therefore, moisture content and and change procedure can reflect the change procedure of oil-water common-layer original saturation ratio.Oozing mutually on the plot of water cut, when moisture content was 0%, corresponding water saturation was the original water saturation of net pay zone; General when moisture content is 10%-90%, corresponding water saturation is the water saturation of oil-water common-layer.Under the condition of certain moisture content (is 50% o'clock as moisture content), the difference of oil-water common-layer water saturation and net pay zone water saturation can be used as oil-water common-layer water saturation correcting value, shown in Figure 5 referring in the Figure of description.
Ooze the moisture content model mutually in order to set up, preferred 3 samples of 1 mouthful of well of local area ooze data mutually, these 3 sample air permeability variation scopes are 373mD～4139mD, average out to 2623.67mD; The effecive porosity excursion is 27.2%～31.1%, and average out to 29.6% has been represented the variation of whole district's effecive porosity preferably.The analysis of oozing mutually that these 3 sample laboratories are recorded shows: for moisture content is the oil-water common-layer of certain value, and oil-water common-layer oil saturation correcting value increases with the increase of reservoir porosity; Because " looking the original water saturation of oil reservoir " also the increase with reservoir porosity increases, therefore, oil-water common-layer water saturation correcting value increases with the increase of " looking the original water saturation of oil reservoir ".In the time of can setting up different water cut rate Fw thus, oil-water common-layer oil saturation correction amount delta So is with the calibration model of " looking oil reservoir initial oil saturation So ", shown in Figure 11 referring in the Figure of description:
When Fw=90%, Δ So=1.592So-77.82 R 2=0.851;
When Fw=80%, Δ So=1.314So-64.05 R 2=0.812;
When Fw=70%, Δ So=1.029So-49.35 R 2=0.740;
When Fw=60%, Δ So=0.7682So-35.80 R 2=0.670;
When Fw=50%, Δ So=0.5520So-24.70 R 2=0.583;
When Fw=40%, Δ So=0.3583So-14.89 R 2=0.448;
When Fw=30%, Δ So=0.2167So-8.108 R 2=0.319;
When Fw=20%, Δ So=0.0956So-2.549 R 2=0.150.
Step 7, obtain the actual moisture content of the oil-water common-layer of formation testing, and select oil saturation calibration model corresponding in the step 6, and then obtain actual oil saturation So according to described moisture content With layer=So+ Δ So.
As seen from Figure 11: for the oil-water common-layer of formation testing, can obtain moisture content Fw, select suitable updating formula to calculate oil saturation correction amount delta So according to Fw according to the formation testing result; If reservoir producing water ratio Fw is between the producing water ratio Fw of certain two formula 1, Fw 2Between, can calculate oil saturation correction amount delta So respectively with these two formula 1, Δ So 2, and result of calculation is carried out linear interpolation obtain final oil saturation correction amount delta So:
ΔSo = Δ So 1 + ( ΔSo 2 - Δ So 1 ) Fw - Fw 1 Fw 2 - Fw 1
According to " looking the oil reservoir initial oil saturation " So that step 5 is calculated, just can use the wet oil saturation ratio of determining oil-water common-layer with layer water saturation correction amount delta So:
So With layer=So+ Δ So.
When needs obtain the original water saturation of formation testing oil-water common-layer not, continue to carry out next step:
Step 8, obtain the not initial oil saturation of formation testing oil-water common-layer:
For calculating the not initial oil saturation of formation testing oil-water common-layer, the average moisture content of statistics local area: single examination oil-water common-layer that local area does not carry out the pressure break formation testing has 10 layers of 10 mouthfuls of wells, and its average moisture content is 44.8%.
3 samples described in the applying step six ooze data mutually, setting up moisture content is 44.8% o'clock, the relational model of oil-water common-layer oil saturation correcting value and same layer " looking the oil reservoir oil saturation ", referring to the Figure 12 in the Figure of description, can calculate the not initial oil saturation correcting value of formation testing oil-water common-layer, and then the oil saturation of definite oil-water common-layer:
During Fw=44.8%: Δ So=-0.4490So-19.47 R 2=0.521.
In order to verify the precision of calculation results of the described method of present embodiment, result of calculation and 3 oil-water common-layer original saturation ratios of 1 mouthful of well actual measurement are contrasted, and concrete parameter is referring to table 2, and its average relative error is 2.7%, less than 8%, satisfy the requirement of reserves standard.
Table 2: oil-water common-layer original saturation ratio precision contrast table
Figure A200810209591D00211

Claims (6)

1, obtain the method for oil-water common-layer original saturation ratio, its detailed process is:
Step 1, obtain natural gamma relative value Δ GR according to the gamma ray log curve:
On the gamma ray log curve, read natural gamma value GR, the interval of interest sharp sand rock stratum natural gamma value GR of oil-water common-layer MinWith interval of interest pure shale interval natural gamma value GR Max, then by formula:
ΔGR＝(GR-GR min)/(GR max-GR min)
Obtain natural gamma relative value Δ GR, wherein target zone natural gamma value GR, interval of interest sharp sand rock stratum natural gamma value GR MinWith interval of interest pure shale layer natural gamma value GR MaxUnit all are API, the unit of natural gamma relative value Δ GR is f;
Step 2, set up the shale content interpretation model:
Carry out one-variable linear regression with core analysis shale content data and natural gamma, set up the shale content interpretation model:
V sh＝a·ΔGR+b，
Shale content V wherein ShBe percentage, a, b are coefficients; The described shale content interpretation model of natural gamma relative value Δ GR substitution of the oil-water common-layer that step 1 is obtained obtains the shale content V of oil-water common-layer Sh
Step 3, set up the effecive porosity interpretation model:
Use acoustic travel time logging curve, shale content and core analysis effecive porosity and carry out binary linear regression, set up the effecive porosity interpretation model:
φ＝a·AC+b·V sh+c，
Effecive porosity φ is a percentage, and a, b, c are coefficients;
The interval transit time value AC of oil-water common-layer, the shale content value V that step 2 obtains will be read ShSubstitution effecive porosity interpretation model, the effecive porosity φ of acquisition oil-water common-layer;
Step 4, in the oil reservoir of sealed coring well, set up the original water saturation model of oil reservoir:
Utilize the relation of irreducible water saturation and air permeability to set up the irreducible water saturation interpretation model, promptly determine the original water saturation model of oil reservoir, be i.e. the original water saturation model of rerum natura by air permeability:
Sw Oil=f (K),
Sw in the formula OilBe the original water saturation of oil reservoir, unit is a percentage, and f () is the empirical function between water saturation and the permeability, usually may be linear function, power function, exponential function or logarithmic function, concrete function can preferably draw by index of correlation, and K is an air permeability, and unit is mD:
Step 5, set up the not original water saturation interpretation model of core hole oil reservoir:
According to the original moisture full water saturation that obtains the conventional layer of coring of the described oil reservoir of step 4, and carry out binary linear regression with effecive porosity, dark side direction resistivity, set up the not original water saturation interpretation model of core hole oil reservoir, promptly electrical original water saturation model:
logS w＝a·logφ+b·logR LLD+c，
R in the formula LLDBe dark side direction resistivity, unit is Ω m, and a, b, c are coefficients;
Oil-water common-layer is considered as oil reservoir, with the dark side direction resistivity R of the local area oil-water common-layer that reads LLD, the oil-water common-layer that will obtain according to the described effecive porosity interpretation model of step 3 the effecive porosity φ substitution original water saturation interpretation model of core hole oil reservoir not, obtain oil-water common-layer " looking the oil reservoir initial oil saturation ";
Step 6, set up a plurality of different water cut rate correspondences oil-water common-layer water saturation correction amount delta Sw with and look calibration model between the original water saturation Sw of oil reservoir:
ΔSw＝a·Sw+b，
In the formula oil-water common-layer look oil reservoir water saturation Sw, oil-water common-layer water saturation correction amount delta Sw all is a percentage, a, b are coefficients;
Step 7, obtain the actual wet oil saturation ratio Sw of the oil-water common-layer of formation testing With layer, and then obtain oil saturation So With layer:
For the oil-water common-layer of formation testing, look oil reservoir water saturation Sw according to what step 5 obtained this layer, and obtain moisture content according to the formation testing result, select the calibration model in the step 6 to obtain oil-water common-layer water saturation correction amount delta Sw under this moisture content condition according to described moisture content again, determine the actual wet oil saturation ratio Sw of oil-water common-layer With layer:
Sw With layer=Sw+ Δ Sw,
The actual water saturation Sw of oil-water common-layer in the formula With layerBe percentage,
Because the water saturation and the oil saturation sum of oil-water common-layer are 100, and then can determine the actual oil saturation So of oil-water common-layer With layer=100-Sw With layer
2, the method for acquisition oil-water common-layer original saturation ratio according to claim 1 is characterized in that determining according to actual conditions in a plurality of different water cut rates described in the step 6.
3, the method for acquisition oil-water common-layer original saturation ratio according to claim 1 is characterized in that, evenly is divided into a plurality of intervals between 0% to 100%, and described a plurality of different water cut rates are each interval endpoint values.
4, according to the method for claim 1 or 2 or 3 described acquisition oil-water common-layer original saturation ratios, it is characterized in that in the step 7 selecting the method for the calibration model in the corresponding step 6 to be: the corresponding calibration model of moisture content of selecting the difference minimum of the described a plurality of different water cut rates of described moisture content and step 6 according to the moisture content of the oil-water common-layer of formation testing.
5, according to the method for claim 1 or 2 or 3 described acquisition oil-water common-layer original saturation ratios, it is characterized in that in the step 7 according to the moisture content of the oil-water common-layer of formation testing, the method of selecting calibration model in the corresponding step 6 to obtain oil-water common-layer water saturation correction amount delta Sw is: select respectively with step 6 in two calibration models that moisture content corresponding adjacent with described moisture content calculate respectively and obtain two correcting values, use approach based on linear interpolation calculating oil-water common-layer water saturation correction amount delta Sw then.
6, estimate the not method of formation testing oil-water common-layer original saturation ratio, it comprises the method for the described acquisition oil-water common-layer original of claim 1 saturation ratio, it is characterized in that it also comprises:
Step 8, obtain the not initial oil saturation of formation testing oil-water common-layer:
Add up the moisture content in all each districts, and the average moisture content of the calculating whole district, use then and ooze data mutually, when setting up moisture content and being average moisture content, the relational model of oil-water common-layer water saturation correcting value and same layer " looking the oil reservoir water saturation ", obtaining the not original water saturation correcting value of formation testing oil-water common-layer, and then the water saturation of definite oil-water common-layer, is the oil saturation that 100 condition obtains oil-water common-layer according to water saturation and oil saturation sum then.
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CN106401575A (en) * 2015-07-29 2017-02-15 中国石油化工股份有限公司 Calculating method for initial oil saturation in water flooded layer of core drilling well during high water cut period
CN105116466A (en) * 2015-07-30 2015-12-02 中国石油天然气股份有限公司 Method and device for determining oil field reservoir physical property characteristics
CN105116466B (en) * 2015-07-30 2017-12-19 中国石油天然气股份有限公司 Method and device for determining oil field reservoir physical property characteristics
CN106503295A (en) * 2016-09-22 2017-03-15 中国石油天然气股份有限公司 Method and device for explaining oil field water flooded layer by using state space model
CN106503295B (en) * 2016-09-22 2019-08-06 中国石油天然气股份有限公司 Method and device for explaining oil field water flooded layer by using state space model
CN106771071A (en) * 2016-12-26 2017-05-31 中国石油天然气集团公司 A kind of sealing core drilling saturation correction method mutually oozed based on profit
CN107479101A (en) * 2017-08-09 2017-12-15 徐彬 Oil saturation analytical equipment
CN107780923A (en) * 2017-11-01 2018-03-09 中石化石油工程技术服务有限公司 A kind of foundation of the water-saturation model based on Shale Correction, emulation mode
CN107780923B (en) * 2017-11-01 2021-04-20 中石化石油工程技术服务有限公司 Method for establishing and simulating water saturation model based on argillaceous correction
CN108593514A (en) * 2018-03-26 2018-09-28 中国石油化工股份有限公司 Oil-water relative permeability based on reservoir properties characterizes processing method
CN111485875A (en) * 2020-04-24 2020-08-04 克拉玛依市昂科能源科技有限公司 Method for evaluating saturation degree of isochronous residual oil
CN113153284A (en) * 2021-04-30 2021-07-23 中国石油天然气股份有限公司 Method, device, equipment and storage medium for determining bound water saturation parameter
CN113153284B (en) * 2021-04-30 2023-06-30 中国石油天然气股份有限公司 Method, device, equipment and storage medium for determining constraint water saturation parameter
CN113216945A (en) * 2021-05-08 2021-08-06 中国石油天然气股份有限公司 Permeability quantitative evaluation method for tight sandstone reservoir
CN113216945B (en) * 2021-05-08 2023-06-20 中国石油天然气股份有限公司 Quantitative evaluation method for permeability of tight sandstone reservoir

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Application publication date: 20090422